SOUTH JERSEY GAS 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 GAS Co
Entity Central Index Key	1,035,216
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-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		2,339,139
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0

STATEMENTS OF INCOME

STATEMENTS OF INCOME - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Statement [Abstract]
Operating Revenues	$ 461,055	$ 534,290	$ 501,875
Operating Expenses:
Cost of Sales (Excluding depreciation)	174,390	245,290	231,216
Operations	95,609	107,836	102,428
Maintenance	17,549	16,183	13,457
Depreciation	47,432	41,365	37,324
Energy and Other Taxes	3,620	4,031	3,760
Total Operating Expenses	338,600	414,705	388,185
Operating Income	122,455	119,585	113,690
Other Income and Expense	3,831	3,844	5,560
Interest Charges	(17,875)	(19,906)	(17,872)
Income Before Income Taxes	108,411	103,523	101,378
Income Taxes	(39,366)	(36,945)	(34,895)
Net Income	$ 69,045	$ 66,578	$ 66,483

STATEMENTS OF COMPREHENSIVE INC

STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Comprehensive Income [Abstract]
Net Income		$ 69,045	$ 66,578	$ 66,483
Other Comprehensive Income (Loss), Net of Tax:
Postretirement Liability Adjustment	[1]	(2,197)	1,617	(3,165)
Unrealized Gain (Loss) on Available-for-Sale Securities	[1]	98	(23)	(472)
Unrealized Gain on Derivatives - Other	[1]	27	23	27
Net current period other comprehensive income	[1],[2]	(2,072)	1,617	(3,610)
Comprehensive Income		$ 66,973	$ 68,195	$ 62,873
Additional Statement Information [Abstract]
Combined statutory rate		40.00%	40.00%	40.00%
[1]	Determined using a combined statutory tax rate of 40% in each of 2016, 2015 and 2014.
[2]	Determined using a combined statutory tax rate of 40%.

STATEMENTS OF CASH FLOWS

STATEMENTS OF CASH FLOWS - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flows from Operating Activities:
Net Income	$ 69,045,000	$ 66,578,000	$ 66,483,000
Provided by Operating Activities:
Depreciation and Amortization	63,901,000	58,668,000	52,155,000
Provision for Losses on Accounts Receivable	6,993,000	14,689,000	9,417,000
CIP Receivable/Payable	(24,943,000)	(7,324,000)	15,226,000
Deferred Gas Costs - Net of Recoveries	11,753,000	28,648,000	(44,976,000)
Deferred SBC Costs - Net of Recoveries	(7,102,000)	9,557,000	11,048,000
Environmental Remediation Costs - Net of Recoveries	(39,735,000)	(22,058,000)	(8,248,000)
Deferred and Noncurrent Income Taxes and Credits - Net	40,980,000	39,148,000	32,193,000
Gas Plant Cost of Removal	(6,070,000)	(5,096,000)	(4,848,000)
Pension Contribution	0	(12,020,000)	0
Changes in:
Accounts Receivable	(24,867,000)	8,597,000	(14,667,000)
Inventories	2,696,000	11,198,000	(3,820,000)
Prepaid and Accrued Taxes - Net	3,980,000	(7,129,000)	(6,508,000)
Other Prepayments and Current Assets	(448,000)	(9,717,000)	131,000
Gas Purchases Payable	14,879,000	(13,423,000)	(1,873,000)
Accounts Payable and Other Accrued Liabilities	35,982,000	(2,264,000)	11,302,000
Other Assets	(7,065,000)	4,996,000	(7,481,000)
Other Liabilities	2,183,000	1,576,000	(2,006,000)
Net Cash Provided by Operating Activities	142,162,000	164,624,000	103,528,000
Cash Flows from Investing Activities:
Capital Expenditures	(225,287,000)	(207,785,000)	(200,008,000)
Note Receivable	9,916,000	(9,916,000)	0
Net Sale (Purchase) of Restricted Investments in Margin Accounts	6,737,000	1,091,000	(7,281,000)
Net Sale of Restricted Investments from Escrowed Loan Proceeds	0	101,000	0
Investment in Long-Term Receivables	(10,886,000)	(19,033,000)	(13,024,000)
Proceeds from Long-Term Receivables	10,014,000	8,769,000	6,544,000
Net Cash Used in Investing Activities	(209,506,000)	(226,773,000)	(213,769,000)
Cash Flows from Financing Activities:
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(30,100,000)	33,000,000	35,900,000
Proceeds from Issuance of Long-Term Debt	61,000,000	80,000,000	89,000,000
Principal Repayments of Long-Term Debt	(27,909,000)	(11,009,000)	(21,000,000)
Payments for Issuance of Long-Term Debt	(63,000)	(9,000)	(627,000)
Dividends on Common Stock	0	(40,764,000)	(18,201,000)
Additional Investment by Shareholder	65,000,000	0	25,000,000
Tax Deficiency from Restricted Stock Plan	0	(72,000)	(73,000)
Net Cash Provided by Financing Activities	67,928,000	61,146,000	109,999,000
Net Increase (Decrease) in Cash and Cash Equivalents	584,000	(1,003,000)	(242,000)
Cash and Cash Equivalents at Beginning of Period	775,000	1,778,000	2,020,000
Cash and Cash Equivalents at End of Period	1,359,000	775,000	1,778,000
Cash paid during the year for:
Interest (Net of Amounts Capitalized)	18,497,000	19,373,000	17,832,000
Income Taxes (Net of Refunds)	(1,000)	(1,665,000)	(7,690,000)
Supplemental Disclosures of Noncash Investing Activities
Capital Expenditures acquired on account but not paid at year-end	$ 25,275,000	$ 24,857,000	$ 17,551,000

BALANCE SHEETS

BALANCE SHEETS - USD ($) $ in Thousands	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)
Property, Plant and Equipment - Net	1,952,912	1,770,766
Investments:
Available-for-Sale Securities	0	8,788
Restricted Investments	32	6,769
Total Investments	32	15,557
Current Assets:
Cash and Cash Equivalents	1,359	775
Notes Receivable	0	9,916
Accounts Receivable	69,651	64,445
Accounts Receivable - Related Parties	1,355	1,972
Unbilled Revenues	41,754	25,613
Provision for Uncollectibles	(12,570)	(9,778)
Natural Gas in Storage, average cost	11,621	14,294
Materials and Supplies, average cost	914	937
Prepaid Taxes	16,428	21,483
Derivatives - Energy Related Assets	5,434	1,077
Other Prepayments and Current Assets	13,853	13,405
Total Current Assets	149,799	144,139
Regulatory and Other Noncurrent Assets:
Regulatory Assets	410,746	323,434
Long-Term Receivables	25,758	24,950
Derivatives - Energy Related Assets	373	64
Other	12,303	2,666
Total Regulatory and Other Noncurrent Assets	449,180	351,114
Total Assets	2,551,923	2,281,576
Common Equity:
Common Stock, Par Value $2.50 per share: Authorized - 4,000,000 shares, Outstanding - 2,339,139 shares	5,848	5,848
Other Paid-In Capital and Premium on Common Stock	315,827	250,827
Accumulated Other Comprehensive Loss	(14,934)	(12,862)
Retained Earnings	533,159	464,114
Total Common Equity	839,900	707,927
Long-Term Debt (See Note 1)	423,177	577,454
Total Capitalization	1,263,077	1,285,381
Current Liabilities:
Notes Payable	104,300	134,400
Current Portion of Long-Term Debt	215,909	27,909
Accounts Payable - Commodity	23,815	8,936
Accounts Payable - Other	45,370	40,579
Accounts Payable - Related Parties	11,216	7,552
Derivatives - Energy Related Liabilities	1,372	5,489
Derivatives - Other Current	386	0
Customer Deposits and Credit Balances	45,816	19,531
Environmental Remediation Costs	45,018	48,323
Taxes Accrued	855	1,930
Pension Benefits	2,428	2,227
Interest Accrued	5,369	5,989
Other Current Liabilities	8,011	5,686
Total Current Liabilities	509,865	308,551
Regulatory and Other Noncurrent Liabilities:
Regulatory Liabilities	49,121	42,841
Deferred Income Taxes - Net	469,408	432,674
Environmental Remediation Costs	108,029	74,871
Asset Retirement Obligations	58,674	57,219
Pension and Other Postretirement Benefits	81,800	65,491
Derivatives - Energy Related Liabilities	0	351
Derivatives - Other	6,979	7,631
Other	4,970	6,566
Total Regulatory and Other Noncurrent Liabilities	778,981	687,644
Commitments and Contingencies (Note 12)
Total Capitalization and Liabilities	$ 2,551,923	$ 2,281,576

BALANCE SHEETS (Parenthetical)

BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Common stock, par value (in USD per share)	$ 2.50	$ 2.50
Common stock, shares authorized (in shares)	4,000,000	4,000,000
Common stock, shares outstanding (in shares)	2,339,139	2,339,139

STATEMENTS OF CHANGES IN COMMON

STATEMENTS OF CHANGES IN COMMON EQUITY AND COMPREHENSIVE INCOME - USD ($) $ in Thousands		Total		Common Stock	Other Paid-In Capital and Premium on Common Stock	Accumulated Other Comprehensive Loss		Retained Earnings	Postretirement Liability Adjustment		Unrealized Gain (Loss) on Available-for-Sale Securities		Unrealized Gain (Loss) on Derivatives
Beginning balance at Dec. 31, 2013		$ 610,969		$ 5,848	$ 225,972	$ (10,869)		$ 390,018
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		66,483						66,483
Other Comprehensive Gain (Loss), Net of Tax		(3,610)	[1],[2]			(3,610)	[2],[3]		$ (3,165)	[3]	$ (472)	[3]	$ 27	[3]
Cash Dividends Declared – Common Stock		(18,201)						(18,201)
Additional Investment by Shareholder		25,000			25,000
Tax Deficiency from Restricted Stock Plan		(73)			(73)
Ending balance at Dec. 31, 2014		$ 680,568		5,848	250,899	(14,479)		438,300
Additional Statement Information [Abstract]
Combined statutory rate		40.00%
Beginning balance at Dec. 31, 2013	[3]					(10,869)			(10,672)		397		(594)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Changes During Year		$ (3,610)	[1],[2]			(3,610)	[2],[3]		(3,165)	[3]	(472)	[3]	27	[3]
Ending balance at Dec. 31, 2014	[3]					(14,479)			(13,837)		(75)		(567)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		66,578						66,578
Other Comprehensive Gain (Loss), Net of Tax		1,617	[1],[2]			1,617	[2],[3]		1,617	[3]	(23)	[3]	23	[3]
Cash Dividends Declared – Common Stock		(40,764)						(40,764)
Tax Deficiency from Restricted Stock Plan		(72)			(72)
Ending balance at Dec. 31, 2015		$ 707,927		5,848	250,827	(12,862)		464,114
Additional Statement Information [Abstract]
Combined statutory rate		40.00%
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Changes During Year		$ 1,617	[1],[2]			1,617	[2],[3]		1,617	[3]	(23)	[3]	23	[3]
Ending balance at Dec. 31, 2015		(12,862)				(12,862)	[3]		(12,220)	[3]	(98)	[3]	(544)	[3]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		69,045						69,045
Other Comprehensive Gain (Loss), Net of Tax		(2,072)	[1],[2]			(2,072)	[2],[3]		(2,197)	[3]	98	[3]	27	[3]
Additional Investment by Shareholder		65,000			65,000
Ending balance at Dec. 31, 2016		$ 839,900		$ 5,848	$ 315,827	(14,934)		$ 533,159
Additional Statement Information [Abstract]
Combined statutory rate		40.00%
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Changes During Year		$ (2,072)	[1],[2]			(2,072)	[2],[3]		(2,197)	[3]	98	[3]	27	[3]
Ending balance at Dec. 31, 2016		$ (14,934)				$ (14,934)	[3]		$ (14,417)	[3]	$ 0	[3]	$ (517)	[3]
[1]	Determined using a combined statutory tax rate of 40% in each of 2016, 2015 and 2014.
[2]	Determined using a combined statutory tax rate of 40%.
[3]	Determined using a combined statutory tax rate of 40%.

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 : The Entity - South Jersey Industries, Inc. (SJI) owns all of the outstanding common stock of South Jersey Gas Company (SJG). In our opinion, the financial statements reflect all normal and recurring adjustments needed to fairly present our financial position and operating results at the dates and for the periods presented. Certain reclassifications have been made to the prior period's balance sheets, as well as the prior period's long-term debt carrying value in Note 8, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the 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 8 to be adjusted. 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 our balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary. No impairment losses were recorded on Investments during 2016 , 2015 or 2014 . Estimates and Assumptions - We prepare our 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 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 - We are subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 3 for a detailed discussion of our rate structure and regulatory actions. We maintain our accounts according to the BPU’s prescribed Uniform System of Accounts. We follow the accounting for regulated enterprises prescribed by the FASB 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 4 for a detailed discussion of regulatory assets and liabilities. Operating Revenues - Gas revenues are recognized in the period the commodity is delivered to customers. For retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas delivered from the date of the last meter reading to the end of the month. Revenue and Throughput-Based Taxes - SJG collects certain revenue-based energy taxes from our 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 revenues and cost of sales 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 balance sheets, and represents natural gas that will be utilized in the ordinary course of business. Property, Plant & Equipment - For regulatory purposes, utility plant is stated at original cost, which may be different than our cost if the assets were acquired from another regulated entity. The cost of adding, replacing and renewing property is charged to the appropriate plant account. Utility Plant balances as of December 31, 2016 and 2015 were comprised of the following (in thousands): 2016 2015 Utility Plant: Production Plant $ 296 $ 296 Storage Plant 60,661 20,872 Transmission Plant 257,169 252,934 Distribution Plant 1,871,703 1,702,148 General Plant 169,464 163,420 Other Plant 1,855 1,855 Utility Plant in Service 2,361,148 2,141,525 Construction Work in Progress 62,986 69,714 Total Utility Plant $ 2,424,134 $ 2,211,239 The increase in Utility Plant in Service is related to the installation of the Liquefied Natural Gas (LNG) liquefier along with projects for distribution, some of which are part of the Company's Accelerated Infrastructure Replacement Program (AIRP), as discussed under Note 3. Asset Retirement Obligations - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations we have to cut and cap our 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 during 2016 and 2015 was as follows (in thousands): 2016 2015 ARO as of January 1, $ 57,219 $ 41,976 Accretion 1,908 1,658 Additions 1,098 621 Settlements (1,551 ) (1,110 ) Revisions in Estimated Cash Flows * — 14,074 ARO as of December 31, $ 58,674 $ 57,219 * The revision in estimated cash flows in 2015 reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings. 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. Capitalized Interest - We capitalize interest on construction at the rate of return on rate base utilized by the BPU to set rates in our last base rate proceeding. For our accelerated infrastructure programs, we capitalize interest on construction at a rate prescribed by the programs (see Note 3). Capitalized interest is included in Utility Plant on the balance sheets. Interest Charges are presented net of capitalized interest on the statements of income. We capitalized interest of $5.3 million in 2016 , $2.8 million in 2015 and $4.4 million in 2014 . The increase in 2016 represents the interest on the Company's investment in Utility Plant under the BPU-approved AIRP program. Under the AIRP, qualified capital expenditures continued to accrue interest on construction until such projects were rolled into customer rates and recovery of the expenditures commenced. 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 2016 , 2015 and 2014 , no significant impairments were identified. Derivative Instruments - SJG uses a variety of derivative instruments to limit its exposure to market risk in accordance with strict guidelines (see Note 14). 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 balance sheets. The costs or benefits of these short-term contracts are recoverable through SJG’s Basic Gas Supply Service (BGSS) clause, subject to BPU approval. As a result, the net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the balance sheets. SJG has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives-Other on the balance sheets. The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates. Subject to BPU approval, the market value upon termination of these interest rate derivatives can be recovered in rates and, therefore, these unrealized losses have been included in Other Regulatory Assets in the balance sheets. Income Taxes - Deferred income taxes are provided for all significant temporary differences between the book and taxable basis of assets and liabilities in accordance with FASB ASC Topic 740 – “Income Taxes” (See Note 6). 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. 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. 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 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 service providers 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 beginning after December 15, 2015 and interim periods within those annual periods, 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 "The Entity" 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.

STOCK-BASED COMPENSATION PLANS

STOCK-BASED COMPENSATION PLANS	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
STOCK-BASED COMPENSATION PLANS	STOCK-BASED COMPENSATION PLANS: Officers and other key employees of SJG participate in the plans of SJI. Performance-based restricted shares vest over a three -year period and are subject to SJI achieving certain market and earnings-based performance targets which can cause the actual amount of shares that ultimately vest to range from 0% to 200% of the original share units granted. Beginning in 2015, SJI grants time-based shares of restricted stock, one-third of which vest annually over a three -year period and is limited to 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, payment is solely contingent upon the service requirement being met in years two and three of the grant. In 2016 and 2015, SJG Officers and other key employees were granted 9,965 and 7,878 shares of time-based restricted stock, respectively. 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 include pre-defined EGR and ROE goals to measure performance. Beginning in 2016, performance targets included 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. We are allocated a portion of SJI's compensation cost during the vesting period. We accrue a liability and record compensation cost over the requisite three -year service period based on the grant date fair value as described above for each type of grant. Upon vesting, we make a cash payment to SJI equal to the amounts accrued as compensation cost during the vesting period. Since the inception of the plans, our expense recognition policy has been consistent with the expense recognition policy at SJI. The following table summarizes the SJI nonvested restricted stock awards pertaining to SJG outstanding at December 31, 2016 , and the assumptions used to estimate the fair value of the awards: Grant Date Shares Outstanding Fair Value Per Share Expected Volatility Risk-Free Interest Rate 2015 - TSR 6,884 $ 26.31 16.0 % 1.10 % 2015 - EPS, ROE, Time 15,211 $ 29.47 n/a n/a 2016 - TSR 11,472 $ 22.53 18.1 % 1.31 % 2016 - CEGR, Time 21,305 $ 23.52 n/a n/a 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 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. The cost for restricted stock awards was $0.6 million , $0.3 million and $0.2 million in 2016 , 2015 and 2014 , respectively. Of these costs, approximately one half was capitalized to Utility Plant in each of those years. As of December 31, 2016 , there was $0.7 million of total unrecognized compensation cost related to nonvested share-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: Shares Weighted Average Grant Date Fair Value Nonvested Shares Outstanding, January 1, 2016 46,475 $ 26.67 Granted 33,218 $ 23.17 Vested* (21,995 ) $ 24.88 Cancelled/Forfeited** (2,826 ) $ 25.89 Nonvested Shares Outstanding, December 31, 2016 54,872 $ 25.31 * Based on performance information available at the filing of this report, management expects to award 5,593 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 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, 2,610 shares were awarded to Officers and other key employees during 2016 at a market value of $0.1 million . SJG has a policy of making cash payments to SJI to satisfy its obligations under the Plan. Cash payments to SJI during 2016 , 2015 and 2014 were approximately $0.2 million , $0.2 million and $0.4 million , respectively, relating to stock awards. Additionally, a change in control could result in the nonvested shares becoming nonforfeitable or immediately payable in cash.

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 17). 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 our 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 our 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 it 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 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 12). 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 balance sheet under Regulatory Assets (See Note 4). 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 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 ongoing 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 us. Customers choosing to purchase natural gas from providers other than the utility are charged for the cost of gas by the marketer. The resulting decrease in SJG's 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 recover 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 our 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 4). Filings and petitions described above are still pending, unless otherwise indicated.

REGULATORY ASSETS AND LIABILITI

REGULATORY ASSETS AND LIABILITIES	12 Months Ended
	Dec. 31, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
REGULATORY ASSETS AND LIABILITIES	REGULATORY ASSETS AND LIABILITIES: The discussion under Note 3, Rates and Regulatory Actions, is integral to the following explanations of specific regulatory assets and liabilities. Regulatory Assets at December 31 consisted of the following items (in thousands): 2016 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. We are currently permitted to recover interest on our Environmental Remediation Costs, Societal Benefit Costs Receivable, Energy Efficiency Tracker and Pipeline Integrity Costs, while the other assets are being recovered without a return on investment. Environmental Remediation Costs - We have two regulatory assets associated with environmental costs related to the cleanup of 12 sites where we or our 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 us 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. We recorded this estimated amount as a regulatory asset with the corresponding current and noncurrent liabilities on the balance sheets under the captions "Current Liabilities" and "Regulatory and Other Noncurrent Liabilities." The BPU allows us to recover the deferred costs over seven -year periods after they are spent (See Notes 3 and 12). 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 Costs - This regulatory asset resulted from the recording of asset retirement obligations (ARO) and additional utility plant, primarily related to a legal obligation we have for certain safety requirements upon the retirement of our gas distribution and transmission system. We recover 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 we are currently recovering in rates and, as such, we are deferring such differences as regulatory assets. Deferred Pension and Other Postretirement Benefit Costs - The BPU authorized us 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 our 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 11). 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 3). Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval (see Note 14). 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 3). Deferred Interest Rate Contracts - These amounts represent the market value of interest rate derivatives as discussed further in Note 13. Energy Efficiency Tracker - This regulatory asset represents cumulative investments less recoveries under the Energy Efficiency Program (See Note 3). Pipeline Supplier Service Charges - This regulatory asset represents costs necessary to maintain adequate supply and system pressures, which are being recovered on a monthly basis through the BGSS over the term of the underlying supplier contracts (see Note 3). Pipeline Integrity Cost - As part of our September 2014 base rate increase, we were permitted to recover previously deferred pipeline integrity costs incurred through September 2014. In addition, we are authorized to defer future program costs, including related carrying costs, for recovery in our next base rate proceeding, subject to review by the BPU (see Note 3). 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 at December 31 consisted of the following items (in thousands): 2016 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 our September 2014 base rate increase, we are required to amortize approximately $1.1 million of this balance to depreciation expense each year. Deferred Revenue - Net - The BGSS changed from a $2.7 million regulatory asset at December 31, 2015 to a $17.8 million regulatory liability at December 31, 2016, primarily due to the gas costs recovered from customers exceeding the actual cost of the commodity. See previous discussion under "Deferred Gas Costs - Net" above. Societal Benefit Costs Payable - This regulatory liability primarily represents cumulative costs less recoveries under the USF and CLEP programs (see Note 3).

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS : We conducted business with our parent, SJI, and several other related parties. A description of each of these affiliates and related transactions is as follows: South Jersey Energy Solutions, LLC (SJES) - a wholly owned subsidiary of SJI that serves as a holding company for all of SJI’s nonutility operating businesses: • South Jersey Energy Company (SJE) - a wholly owned subsidiary of SJES and a third party energy marketer that acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers. We provide SJE with billing services. For SJE’s commercial customers, for which we perform billing services, we purchase the related accounts receivable at book value and charge them a purchase of receivable fee (POR) for potential uncollectible accounts, and assume all risk associated with collection. • South Jersey Resources Group, LLC (SJRG) - a wholly owned subsidiary of SJES and a wholesale gas and risk management business that supplies natural gas storage, commodity and transportation to retail marketers, utility businesses and electricity generators in the mid-Atlantic, Appalachian and southern states. We sell natural gas for resale and capacity release to SJRG and also meet some of our gas purchasing requirements by purchasing natural gas from SJRG. Additionally, prior to 2015, SJRG had managed some of our market risk associated with fluctuations in the cost of natural gas by entering into financial derivative contracts on our behalf. The gain or loss associated with these derivative contracts was included in our BGSS and in the SJRG receivable and payable amounts shown below. • Marina Energy LLC (Marina) - a wholly owned subsidiary of SJES and developer, owner and operator of energy related projects. We provide natural gas transportation services to Marina under BPU-approved tariffs. • South Jersey Energy Service Plus, LLC (SJESP) - a wholly owned subsidiary of SJES and an appliance service company. We provide billing services to SJESP. Millennium Account Services, LLC (Millennium) - a partnership between SJI and Pepco Holdings, Inc, which reads our utility customers’ meters on a monthly basis for a fee. Sales of gas to SJRG and SJE comply with Section 284.02 of the Regulations of the Federal Energy Regulatory Commission (FERC). In addition to the above, we provide various administrative and professional services to SJI and each of the affiliates discussed above. Likewise, SJI provides substantial administrative services on our behalf. For certain types of transactions, we served as central processing agents for the related parties discussed above. Amounts due to and due from these related parties for pass-through items are not considered material to the financial statements as a whole. A summary of these related party transactions, excluding pass-through items, included in Operating Revenues were as follows (in thousands): 2016 2015 2014 Operating Revenues/Affiliates: SJRG $ 6,934 $ 5,342 $ 959 Marina 386 602 1,083 Other — 5 — Total Operating Revenues/Affiliates $ 7,320 $ 5,949 $ 2,042 Related party transactions, excluding pass-through items, included in Operating Expenses were as follows (in thousands): 2016 2015 2014 Costs of Sales/Affiliates (Excluding depreciation): SJRG $ 16,306 $ 26,090 $ 15,265 Derivative Losses/ (Gains) (See Note 1): SJRG $ — $ 64 $ (1,582 ) Operations Expense/Affiliates: SJI $ 20,296 $ 14,088 $ 14,110 Millennium 2,803 2,746 2,668 Other (198 ) (412 ) (434 ) Total Operations Expense/Affiliates $ 22,901 $ 16,422 $ 16,344

INCOME TAXES AND CREDITS

INCOME TAXES AND CREDITS	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
INCOME TAXES AND CREDITS	INCOME TAXES AND CREDITS : 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 $ 37,944 $ 36,233 $ 35,482 Increase (Decrease) Resulting from: State Income Taxes 4,096 4,584 1,935 Amortization of Investment Tax Credits — (149 ) (211 ) ESOP Dividend (1,170 ) (1,168 ) (1,109 ) AFUDC (900 ) (1,109 ) (1,481 ) Research and Development Credits (613 ) (1,400 ) — Other - Net 9 (46 ) 279 Total Income Tax Expense $ 39,366 $ 36,945 $ 34,895 The provision for Income Taxes is comprised of the following (in thousands): 2016 2015 2014 Current: Federal $ — $ — $ 60 State (1,614 ) (2,203 ) 2,642 Total Current (1,614 ) (2,203 ) 2,702 Deferred: Federal 33,064 30,042 32,069 State 7,916 9,255 335 Total Deferred 40,980 39,297 32,404 Investment Tax Credits — (149 ) (211 ) Total Income Tax Expense $ 39,366 $ 36,945 $ 34,895 Investment Tax Credits are deferred and amortized at the annual rate of 3% , 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 liabilities at December 31 (in thousands): 2016 2015 Deferred Tax Assets: Net Operating Loss and Tax Credits $ 102,290 $ 64,978 Deferred State tax 24,574 20,825 Provision for Uncollectibles 5,170 4,030 Pension & Other Post Retirement Benefits 17,264 28,464 Deferred Revenues 7,696 4,844 Other 3,573 3,985 Total Deferred Tax Assets $ 160,567 $ 127,126 Deferred Tax Liabilities: Book Versus Tax Basis of Property $ 532,330 $ 480,682 Deferred Fuel Costs - Net 2,052 3,998 Environmental Remediation 33,573 20,408 Deferred Regulatory Costs 1,554 566 Deferred Pension & Other Post Retirement Benefits 34,432 42,216 Budget Billing - Customer Accounts 3,347 830 Section 461 Prepayments 1,147 1,017 Conservation Incentive Program 11,846 1,132 Other 9,694 8,951 Total Deferred Tax Liabilities $ 629,975 $ 559,800 Deferred Tax Liability - Net $ 469,408 $ 432,674 SJG is included in the consolidated federal income tax return filed by SJI. The actual taxes, including credits, are allocated by SJI to its subsidiaries, generally on a separate return basis except for net operating loss and credit carryforwards. As of December 31, 2016 and 2015, there were no income taxes due to or from SJI. As of December 31, 2016 and 2015, SJG has total federal net operating loss carryforwards of $263.0 million and $179.3 million , respectively, that will expire between 2031 and 2036. SJG has a state net operating loss carryforward of $80.2 million that will expire in 2036. SJG has research and development credits of $2.7 million which will expire between 2031 and 2035. A valuation allowance is recorded when it is more likely than not that any of our deferred income tax assets will not be realized. We believe that we will generate sufficient future taxable income to realize the income tax benefits related to our deferred tax assets. A reconciliation of unrecognized tax benefits is as follows (in thousands): 2016 2015 2014 Balance at January 1, $ 559 $ 552 $ 547 Increase as a result of tax position taken in prior years 802 7 5 Balance at December 31, $ 1,361 $ 559 $ 552 The total unrecognized tax benefits reflected in the table above exclude $0.7 million , of accrued interest and penalties as of December 31, 2016 , 2015 and 2014 . The amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate is not significant. Our 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 benefits in 2016 is attributable to research and development credits.SJG 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 2012 forward are open and subject to examination.

LONG-TERM DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT : A schedule of our long-term debt as of December 31, including current maturities, is as follows (in thousands): 2016 2015 Long-Term Debt (A): First Mortgage Bonds: (B) 5.437 % Series due 2016 (C) — 10,000 4.60 % Series due 2016 (C) — 17,000 4.657 % Series due 2017 15,000 15,000 7.97 % Series due 2018 10,000 10,000 7.125 % Series due 2018 20,000 20,000 5.587 % Series due 2019 10,000 10,000 3.00 % Series due 2024 (D) 50,000 50,000 3.03 % Series due 2024 (E) 35,000 35,000 3.63 % Series due 2025 (F) 8,182 9,091 4.84 % Series due 2026 (G) 15,000 15,000 4.93 % Series due 2026 (H) 45,000 45,000 4.03 % Series due 2027 45,000 45,000 4.01 % Series due 2030 (I) 50,000 50,000 4.23 % Series due 2030 30,000 30,000 3.74 % Series due 2032 35,000 35,000 5.55 % Series due 2033 32,000 32,000 6.213 % Series due 2034 10,000 10,000 5.45 % Series due 2035 10,000 10,000 Series A 2006 Tax-Exempt First Mortgage Bonds Variable Rate, due 2036 (J) 24,900 24,900 Variable Rate Bank Term Facility, due 2017 (K) 200,000 139,000 Total Long-Term Debt Outstanding (L) 645,082 611,991 Less Current Maturities (215,909 ) (27,909 ) Long-Term Debt (L) $ 429,173 $ 584,082 (A) Long-term debt maturities for the succeeding five years are as follows (in thousands): 2017, $215,909 ; 2018, $ 38,909 ; 2019, $18,909 ; 2020, $17,909 ; 2021, $27,909 . (B) Our 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 17). (C) In July 2016, SJG retired $17.0 million aggregate principal amount of 4.6% Medium Term Notes (MTN's) at maturity. In August 2016, SJG retired $10.0 million aggregate principal amount 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 toward the principal amount of 3.63% MTN's annually, 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 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 is $200.0 million , which is classified in current portion of long-term debt on the balance sheets as it is due within one year. In January 2017, this term facility was paid in full (see Note 17). (L) Total Long-Term Debt in the table above does not include unamortized debt issuance costs of $6.0 million and $6.6 million for the years ended December 31, 2016 and 2015, respectively, which were reclassified to Long-Term Debt on the 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.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2016
Financial Instruments, Owned, at Fair Value [Abstract]
FINANCIAL INSTRUMENTS	FINANCIAL INSTRUMENTS: RESTRICTED INVESTMENTS - In accordance with the terms of our tax-exempt first mortgage bonds, unused proceeds are required to be escrowed pending approved construction expenditures. As of both December 31, 2016 and 2015 , the escrowed proceeds, including interest earned, totaled $32,200 . SJG maintains a margin account with a counterparty in conjunction with SJG's risk management activities as detailed in Note 14. The funds provided by SJG will increase or decrease as the number and value of outstanding energy-related contracts held with this counterparty changes. As of December 31, 2016 , the balance owed to this counterparty totaled $3.6 million , which is included in Accounts Payable - Other on the balance sheets. As of December 31, 2015 , the balance held by the counterparty was $6.7 million , which was included in Restricted Investments on the balance sheets. The carrying amounts of the Restricted Investments approximate their fair value at December 31, 2016 and 2015 , which would be included in Level 1 of the fair value hierarchy (see Note 13). NOTE RECEIVABLE - In June 2015, SJG advanced $10.0 million to a not-for profit organization formed to spur economic development in Atlantic City. The note bore interest at 1% 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 Long-Term Receivables on the 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 SJG’s 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 13). 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 SJG's financial instruments that are not carried at fair value, including those financial instruments disclosed in this footnote, 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 SJG at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy; see Note 13). The estimated fair values of SJG's long-term debt, including current maturities, as of December 31, 2016 and 2015 , were $673.1 million and $657.4 million , respectively. The carrying amounts of SJG's long-term debt, including current maturities, as of December 31, 2016 and 2015 , were $639.1 million and $605.4 million , respectively. The carrying amounts as of December 31, 2016 and 2015 are net of unamortized debt issuance costs of $6.0 million and $6.6 million , respectively (see Note 1).

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): Total Facility Usage Available Liquidity Expiration Date Commercial Paper Program/ Revolving Credit Facility $ 200,000 $ 105,100 (A) $ 94,900 May 2018 Uncommitted Bank Lines 10,000 — 10,000 August 2017 Total $ 210,000 $ 105,100 $ 104,900 (A) Includes letters of credit outstanding in the amount of $ 0.8 million . The SJG facility is provided by a syndicate of banks and contains one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the credit agreement) to not more than 0.65 to 1 measured at the end of each fiscal quarter. SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million . The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes. SJG uses the commercial paper program in tandem with the $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million . Average borrowings outstanding under these credit facilities, not including letters of credit, during the twelve months ended December 31, 2016 and 2015 were $71.5 million and $118.1 million , respectively. The maximum amount outstanding under these credit facilities, not including letters of credit, during the twelve months ended December 31, 2016 and 2015 were $ 141.7 million and $ 162.3 million , respectively. Based upon the existing credit facilities and a regular dialogue with our banks, we believe that there will continue to be sufficient credit available to meet our business’ future liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 0.97% , 0.66% and 0.45% at December 31, 2016 , 2015 and 2014 , respectively.

RETAINED EARNINGS

RETAINED EARNINGS	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
RETAINED EARNINGS	RETAINED EARNINGS : Various loan agreements contain potential restrictions regarding the amount of cash dividends or other distributions that we may pay on our common stock. As of December 31, 2016 , these loan restrictions did not affect the amount that may be distributed from our retained earnings. No cash dividends were declared or paid to SJI in 2016. SJG declared and paid cash dividends of $40.7 million in 2015 to SJI. SJG received a $65.0 million and $25.0 million equity infusion from SJI in 2016 and 2014, respectively. Future equity contributions will occur on an as needed basis.

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 : We participate in the defined benefit pension plans and other postretirement benefit plans of SJI. Approximately 50.4% of the Company's current full-time employees will be entitled to annuity payments upon retirement. Participation in the SJI 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 officers of SJG also participate in the non-funded supplemental executive retirement plan (SERP) of SJI, 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 Other Postretirement Benefits 2016 2015 2014 2016 2015 2014 Service Cost $ 4,144 $ 4,430 $ 3,697 $ 576 $ 726 $ 585 Interest Cost 10,292 9,357 8,952 2,120 2,406 2,297 Expected Return on Plan Assets (11,029 ) (11,914 ) (10,818 ) (2,823 ) (2,708 ) (2,467 ) Amortization: Prior Service Cost (Credits) 203 203 177 (257 ) 499 133 Actuarial Loss 7,975 8,969 4,864 945 1,107 770 Net Periodic Benefit Cost 11,585 11,045 6,872 561 2,030 1,318 Capitalized Benefit Costs (4,645 ) (4,805 ) (3,047 ) (277 ) (1,043 ) (722 ) Affiliate SERP Allocations (1,960 ) (1,688 ) (1,313 ) — — — Deferred Benefit Costs (644 ) (1,007 ) — — (256 ) — Total Net Periodic Benefit Expense $ 4,336 $ 3,545 $ 2,512 $ 284 $ 731 $ 596 Capitalized benefit costs reflected in the table above relate to our 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 our 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 we recover all prudently incurred pension and postretirement benefit costs from our ratepayers, a significant portion of the charges resulting from the recording of additional liabilities under this statement are reported as regulatory assets (see Note 4). 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 $ 23,170 $ — Amounts Arising during the Period: Net Actuarial (Gains)/Losses (463 ) (3,155 ) 184 — Prior Service Cost — (499 ) — — Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (6,079 ) (1,107 ) (2,891 ) — Prior Service Cost (203 ) (7,755 ) — — Balance at December 31, 2015 64,432 15,347 20,463 — Amounts Arising during the Period: Net Actuarial Loss 9,706 2,584 6,129 — Prior Service Credit — 257 — — Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (5,485 ) (945 ) (2,490 ) — Prior Service Cost (203 ) — — — Balance at December 31, 2016 $ 68,450 $ 17,243 $ 24,102 $ — 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 Net Actuarial Loss $ 2,378 $ — A reconciliation of the plans’ benefit obligations, fair value of plan assets, funded status and amounts recognized in our balance sheets follows (in thousands): Other Pension Benefits Postretirement Benefits 2016 2015 2016 2015 Change in Benefit Obligations : Benefit Obligation at Beginning of Year $ 213,660 $ 221,605 $ 46,518 $ 60,670 Service Cost 4,144 4,430 576 726 Interest Cost 10,292 9,357 2,120 2,406 Actuarial Loss (Gain) 17,463 (13,107 ) 2,292 (6,257 ) Retiree Contributions — — 70 608 Plan Amendments — — — (7,755 ) Benefits Paid (9,203 ) (8,625 ) (3,027 ) (3,880 ) Benefit Obligation at End of Year $ 236,356 $ 213,660 $ 48,549 $ 46,518 Change in Plan Assets: Fair Value of Plan Assets at Beginning of Year $ 149,032 $ 144,568 $ 43,428 $ 40,951 Actual Return on Plan Assets 12,656 (913 ) 2,531 (395 ) Employer Contributions 2,244 14,002 2,946 6,144 Retiree Contributions — — 70 608 Benefits Paid (9,203 ) (8,625 ) (3,027 ) (3,880 ) Fair Value of Plan Assets at End of Year $ 154,729 $ 149,032 $ 45,948 $ 43,428 Funded Status at End of Year : Accrued Net Benefit Cost at End of Year $ (81,627 ) $ (64,628 ) $ (2,601 ) $ (3,090 ) Amounts Recognized in the Statement of Financial Position Consist of: Current Liabilities $ (2,428 ) $ (2,227 ) $ — $ — Noncurrent Liabilities (79,199 ) (62,401 ) (2,601 ) (3,090 ) Net Amount Recognized at End of Year $ (81,627 ) $ (64,628 ) $ (2,601 ) $ (3,090 ) 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 Net Amount Recognized at End of Year $ 68,450 $ 64,432 $ 17,243 $ 15,347 Amounts Recognized in Accumulated Other Comprehensive Loss Consist of: Net Actuarial Loss $ 24,102 $ 20,463 $ — $ — The projected benefit obligation (PBO) and accumulated benefit obligation (ABO) of our qualified employee pension plans were $183.2 million and $170.0 million , respectively, as of December 31, 2016 ; and $167.6 million and $154.8 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 $154.7 million and $149.0 million as of December 31, 2016 and 2015 , respectively, and can be seen in the tables above. The PBO and ABO for our non-funded SERP were $53.2 million and $51.2 million , respectively, as of December 31, 2016 ; and $46.1 million and $44.6 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 our active and retired plan participants had increased. The obligations as of December 31, 2014, disclosed herein reflect the use of those tables. In 2015, the SOA released an update to the RP-2014 tables (MP-2015 base tables), slightly reducing the average life expectancy previously released. The obligations as of December 31, 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 31 of the year of adoption, the impact on expense does 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 our 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, mid-cap and small-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. SJG 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 SJG’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 13, which will serve as the basis for presentation throughout the remainder of this Note. The fair values of SJG’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 $ 52 $ 52 $ — $ — Common/Collective Trust Funds (a) 376 — 376 — STIF-Type Instrument (b) 1,168 — 1,168 — Equity securities: Common/Collective Trust Funds – U.S. (a) 42,369 — 42,369 — Common/Collective Trust Funds – International (a) 27,017 — 27,017 — U.S. Large-Cap (c) 14,523 14,523 — — U.S. Mid-Cap (c) 2,024 2,024 — — U.S. Small-Cap (c) — — — International (c) 2,727 2,727 — — Fixed Income: Common/Collective Trust Funds (a) 44,873 — 44,873 — Guaranteed Insurance Contract (d) 7,930 — — 7,930 Hedge Funds (e) — — — — Other types of investments: Private Equity Fund (f) 4,164 — — 4,164 Common/Collective Trust Fund – Real Estate (g) 7,506 — — 7,506 Total $ 154,729 $ 19,326 $ 115,803 $ 19,600 Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015 Cash / Cash Equivalents: Cash $ 28 $ 28 — $ — Common/Collective Trust Funds (a) 692 — 692 — STIF-Type Instrument (b) 1,096 — 1,096 — Equity securities: Common/Collective Trust Funds – U.S. (a) 41,976 — 41,976 — Common/Collective Trust Funds – International (a) 26,800 — 26,800 — U.S. Large-Cap (c) 11,535 11,535 — — U.S. Mid-Cap (c) 2,748 2,748 — — U.S. Small-Cap (c) 210 210 International (c) 1,367 1,367 — — Fixed Income: Common/Collective Trust Funds (a) 40,853 — 40,853 — Guaranteed Insurance Contract (d) 8,031 — — 8,031 Hedge Funds (e) 3,353 — — 3,353 Other types of investments: Private Equity Fund (f) 3,477 — — 3,477 Common/Collective Trust Fund – Real Estate (g) 6,866 — — 6,866 Total $ 149,032 $ 15,888 $ 111,417 $ 21,727 (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 the 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 which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 to 120 day lag and, therefore, the value reported herein represents the market value as of June or September 30, 2016 and 2015, 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 2 investments. Fair Value Measurement Using Significant Unobservable Inputs (Level 3) (In thousands) Guaranteed Insurance Contract Hedge Funds Private Equity Funds Real Estate Total Balance at January 1, 2015 $ 8,738 $ 3,469 $ 2,895 $ 5,987 $ 21,089 Actual return on plan assets: Relating to assets still held at the reporting date (26 ) (116 ) (223 ) 879 514 Relating to assets sold during the period 21 — 346 — 367 Purchases, Sales and Settlements (702 ) — 459 — (243 ) Balance at December 31, 2015 $ 8,031 $ 3,353 $ 3,477 $ 6,866 $ 21,727 Actual return on plan assets: Relating to assets still held at the reporting date 541 (13 ) (71 ) 640 1,097 Relating to assets sold during the period 12 — 200 — 212 Purchases, Sales and Settlements (654 ) (3,340 ) 558 — (3,436 ) Balance at December 31, 2016 $ 7,930 $ — $ 4,164 $ 7,506 $ 19,600 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 SJG’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) 13,372 — 13,372 $ — Common/Collective Trust Funds - International (a) 7,796 — 7,796 — Fixed Income: Common/Collective Trust Funds - Bonds (a) 12,167 — 12,167 — Other Types of Investments: Company Owned Life Insurance (c) 12,613 — 12,613 — Total $ 45,948 $ — $ 45,948 $ — Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015 Cash $ 26 $ 26 $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) 12,154 — 12,154 $ — Common/Collective Trust Funds - International (a) 7,471 — 7,471 — Mutual Fund - U.S. (b) 1,228 1,228 — — Mutual Funds - International (b) 922 922 — — Fixed Income: Common/Collective Trust Funds - Bonds (a) 11,852 — 11,852 — Mutual Funds - Bonds (b) 1,352 1,352 — — Other Types of Investments: Mutual Funds - REITS (b) 142 142 — — Company Owned Life Insurance (c) 8,281 — 8,281 — Total $ 43,428 $ 3,670 $ 39,758 $ — (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 $ 10,339 $ 3,600 2018 $ 10,619 $ 3,577 2019 $ 11,472 $ 3,677 2020 $ 11,921 $ 3,790 2021 $ 12,481 $ 3,811 2022 - 2026 $ 73,847 $ 18,131 Contributions - SJG contributed $12.0 million to our qualified employee pension plans during the year ended December 31, 2015 No pension plan contributions were made to our qualified employee pension plans during the years ended December 31, 2016 and 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 $2.4 million in 2017. We also have a regulatory obligation to contribute approximately $3.6 million annually to our other postretirement benefit plans’ trusts, less costs incurred directly by us. Defined Contribution Plan - We also offer an Employees’ Retirement Savings Plan (Savings Plan) to eligible employees. For employees eligible for participation in SJI's defined benefit pension plans, SJG matches 50% of participants’ contributions up to 6% of base compensation. For employees who are not eligible for participation in SJI’s defined benefit plans, we match 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 $1.3 million , $1.2 million and $1.2 million for the years ended December 31, 2016 , 2015 and 2014 , respectively.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES: Standby Letter of Credit - SJG provided a $25.2 million letter of credit under a separate facility outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system. Gas Supply Related Contracts - In the normal course of conducting business, we have entered into long-term contracts for natural gas supplies, firm transportation and gas storage service. The earliest date at which any of the primary terms of these contracts expire is October 2017. The transportation and storage agreements entered into between us and each of our interstate pipeline service providers were done so in accordance with their respective FERC approved tariff. Our cumulative obligation for gas supply related demand charges and reservation fees paid for these services averages approximately $5.6 million per month and is recovered on a current basis through the BGSS. Pending Litigation - SJG is subject to claims arising in the ordinary course of business and other legal proceedings. SJG accrues liabilities related to these claims when SJG can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. SJG is currently involved in a pricing dispute related to a long-term gas supply contract whereby SJG has sued the supplier to recover amounts that were improperly invoiced. Subsequently, the supplier counter-sued SJG claiming it is owed an additional $14.9 million , plus interest, through December 31, 2016 under the same contract. We believe any monies received or paid associated with the SJG claims would reflect gas costs that would be recovered from SJG's customers through adjusted rates. The Company has accrued approximately $0.6 million and $0.8 million related to all claims in the aggregate, as of December 31, 2016 and 2015 , respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows. Collective Bargaining Agreements - Unionized personnel represent approximately 62% of our workforce at December 31, 2016 . The Company has collective bargaining agreements with two unions who represent these employees: the International Brotherhood of Electrical Workers (IBEW) that operates under a collective bargaining agreement that runs through February 2018. The remaining unionized employees are represented by the International Association of Machinists and Aerospace Workers (IAM). Employees represented by the IAM operate under a collective bargaining agreement that runs through August 2017. Environmental Remediation Costs - We incurred and recorded costs for environmental cleanup of 12 sites where we or our predecessors operated gas manufacturing plants. We stopped manufacturing gas in the 1950s. We successfully entered into settlements with all of our historic comprehensive general liability carriers regarding the environmental remediation expenditures at our sites. Also, we had purchased a Cleanup Cost Cap Insurance Policy limiting the amount of remediation expenditures that we were required to make at 11 of our sites. This policy provided coverage up to $50.0 million , which was exhausted in 2012. Since the early 1980s, we accrued environmental remediation costs of $420.2 million , of which $267.2 million has been spent as of December 31, 2016 . The following table details the amounts accrued and expended for environmental remediation at December 31 (in thousands): 2016 2015 Beginning of Year $ 123,194 $ 124,308 Accruals 61,933 18,747 Expenditures (32,080 ) (19,861 ) End of Year $ 153,047 $ 123,194 The balances are segregated between current and noncurrent on the balance sheets under the captions Current Liabilities and Regulatory and Other Noncurrent Liabilities. Management estimates that undiscounted future costs to clean up our sites will range from $153.0 million to $257.1 million . We recorded the lower end of this range, $153.0 million , as a liability because a single reliable estimation point is not feasible due to the amount of uncertainty involved in the nature of projected remediation efforts and the long period over which remediation efforts will continue. Six of our sites comprise the majority of these estimates, the sum of the six sites range from a low of $141.2 million to a high of $246.7 million . Recorded amounts include estimated costs based on projected investigation and remediation work plans using existing technologies. Actual costs could differ from the estimates due to the long-term nature of the projects, changing technology, government regulations and site-specific requirements. Significant risks surrounding these estimates include unforeseen market price increases for remedial services, property owner acceptance of remedy selection, regulatory approval of selected remedy and remedial investigative findings. The remediation efforts at our 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.

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 Derivatives – Energy Related Assets (B) 5,807 4,767 — 1,040 $ 5,807 $ 4,767 $ — $ 1,040 Liabilities Derivatives – Energy Related Liabilities (B) $ 1,372 $ 6 $ 1,252 $ 114 Derivatives – Other (C) 7,365 — 7,365 — $ 8,737 $ 6 $ 8,617 $ 114 As of December 31, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 8,788 $ 1,722 $ 7,066 $ — Derivatives – Energy Related Assets (B) 1,141 398 144 599 $ 9,929 $ 2,120 $ 7,210 $ 599 Liabilities Derivatives – Energy Related Liabilities (B) $ 5,840 $ 5,424 $ — $ 416 Derivatives – Other (C) 7,631 — 7,631 — $ 13,471 $ 5,424 $ 7,631 $ 416 (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. (C) Derivatives – Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands): Type Fair Value at December 31, 2016 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $1,040 $114 Discounted Cash Flow Forward price (per dt) $3.25 - $6.33 Type Fair Value at December 31, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $599 $416 Discounted Cash Flow Forward price (per dt) $1.18 - $5.21 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 $ 183 Other Changes in Fair Value from Continuing and New Contracts, Net 926 Settlements (183 ) Balance at December 31, 2016 $ 926 Year Ended December 31, 2015 Balance at January 1, 2015 $ — Other Changes in Fair Value from Continuing and New Contracts, Net 183 Settlements — Balance at December 31, 2015 $ 183

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVE INSTRUMENTS	DERIVATIVE INSTRUMENTS: SJG is involved in buying, selling, transporting and storing natural gas and is 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, futures contracts, swap agreements and options contracts. As of December 31, 2016 , SJG had outstanding NYMEX contracts intended to limit the exposure to market risk on 8.5 MMdts of expected future purchases of natural gas and 0.6 MMdts of expected future sales of natural gas. In addition to these derivative contracts, SJG had basis related purchase and sales contracts totaling 1.3 MMdts. These contracts, which do not qualify for the normal purchase normal sale exemption and 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 balance sheets. The costs or benefits of these short-term contracts are recoverable through SJG’s BGSS clause, subject to BPU approval. As a result, the net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the balance sheets. As of December 31, 2016 and December 31, 2015 , SJG had $4.4 million of unrealized gains and $(4.7) million of unrealized losses, respectively, included in its BGSS related to open financial contracts. The Company has also entered into interest rate derivatives to manage exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in "Derivatives - Other" on the balance sheets. The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates. Subject to BPU approval, the market value upon termination of these interest rate derivatives can be recovered in rates and therefore these unrealized losses have been included in Regulatory Assets on the balance sheets. We previously used derivative transactions known as “Treasury Locks” to mitigate against the impact on our cash flows of possible interest rate increases on debt issued in September 2005. The initial $1.4 million cost of the Treasury Locks has been included in Accumulated Other Comprehensive Loss and is being amortized over the 30 -year life of the associated debt issue. As of both December 31, 2016 and 2015 , the unamortized balance was approximately $0.9 million . As of December 31, 2016 , SJG’s active interest rate swaps were as follows: Notional Amount Fixed Interest Rate Start Date Maturity Type of Debt Obligor $ 12,500,000 3.53 % 12/1/2006 2/1/2036 Tax-exempt SJG $ 12,500,000 3.43 % 12/1/2006 2/1/2036 Tax-exempt SJG The fair values of all derivative instruments, as reflected in the balance sheets as of December 31, 2016 and 2015 , 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 $ 5,434 $ 1,372 $ 1,077 $ 5,489 Derivatives – Energy Related – Non-Current 373 — 64 351 Interest rate contracts: Derivatives – Other Current 386 — Derivatives – Other Noncurrent — 6,979 — 7,631 Total derivatives not designated as hedging instruments under GAAP $ 5,807 $ 8,737 $ 1,141 $ 13,471 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 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 $ 5,807 $ — $ 5,807 $ (6 ) (A) $ (3,587 ) $ 2,214 Derivatives - Energy Related Liabilities $ (1,372 ) $ — $ (1,372 ) $ 6 (B) $ — $ (1,366 ) Derivatives - Other $ (7,365 ) $ — $ (7,365 ) $ — $ — $ (7,365 ) As of December 31, 2015 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets $ 1,141 $ — $ 1,141 $ (399 ) (A) $ — $ 742 Derivatives - Energy Related Liabilities $ (5,840 ) $ — $ (5,840 ) $ 399 (B) $ 5,025 $ (416 ) Derivatives - Other $ (7,631 ) $ — $ (7,631 ) $ — $ — $ (7,631 ) (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 income for 2016 , 2015 and 2014 are as follows (in thousands): Year ended December 31, Derivatives in Cash Flow Hedging Relationships 2016 2015 2014 Interest Rate Contracts: Losses reclassified from accumulated OCI into income (a) $ (46 ) $ (46 ) $ (46 ) (a) 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 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.

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 tables summarizes the changes in accumulated other comprehensive loss (AOCL) for the years ended December 31, 2016 and 2015 , respectively (in thousands): Postretirement Liability Adjustment Unrealized Gain (Loss) on Derivatives-Other Unrealized Gain (Loss) on Available-for-Sale Securities Total Balance at January 1, 2016 (a) $ (12,220 ) $ (544 ) $ (98 ) $ (12,862 ) Other comprehensive income before reclassifications (3,687 ) — 323 (3,364 ) Amounts reclassified from AOCL (b) 1,490 27 (225 ) 1,292 Net current period other comprehensive income (2,197 ) 27 98 (2,072 ) Balance at December 31, 2016 (a) $ (14,417 ) $ (517 ) $ — $ (14,934 ) Postretirement Liability Adjustment Unrealized Gain (Loss) on Derivatives-Other Unrealized Gain (Loss) on Available-for-Sale Securities Total Balance at January 1, 2015 (a) $ (13,837 ) $ (567 ) $ (75 ) $ (14,479 ) Other comprehensive income before reclassifications (110 ) — (76 ) (186 ) Amounts reclassified from AOCL (b) 1,727 23 53 1,803 Net current period other comprehensive income 1,617 23 (23 ) 1,617 Balance at December 31, 2015 (a) $ (12,220 ) $ (544 ) $ (98 ) $ (12,862 ) (a) Determined using a combined statutory tax rate of 40% in 2016 and 2015 . (b) See table below. The reclassifications out of AOCL for the years ended December 31, 2016 and 2015 is as follows (in thousands): Components of AOCL Amounts Reclassified from AOCL Affected Line Item in the Statements of Income For the Year Ended For the Year Ended Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges $ 46 $ 46 Interest Charges Income Taxes (19 ) (23 ) Income Taxes (a) $ 27 $ 23 Unrealized Loss(Gain) on Available-for-Sale Securities (377 ) 90 Other Income & Expense Income Taxes 152 (37 ) Income Taxes (a) $ (225 ) $ 53 Actuarial Loss on Postretirement Benefits 2,490 2,891 Operating Expenses: Operations Income Taxes (1,000 ) (1,164 ) Income Taxes (a) $ 1,490 $ 1,727 Losses from reclassifications for the period net of tax $ 1,292 $ 1,803 (a) Determined using a combined statutory tax rate of 40% in 2016 and 2015 .

QUARTERLY RESULTS OF OPERATIONS

QUARTERLY RESULTS OF OPERATIONS - UNAUDITED	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
QUARTERLY RESULTS OF OPERATIONS - UNAUDITED	QUARTERLY RESULTS OF OPERATIONS - UNAUDITED: The summarized quarterly results of our operations are as follows (in thousands): 2016 Quarter Ended 2015 Quarter Ended March 31 June 30 Sept. 30 Dec. 31 March 31 June 30 Sept. 30 Dec. 31 Operating Revenues $ 187,766 $ 68,762 $ 62,025 $ 142,502 $ 267,658 $ 75,812 $ 58,634 $ 132,186 Expenses: Cost of Sales (excluding depreciation) 69,303 19,997 26,395 58,695 146,102 25,419 22,934 50,835 Operations and Maintenance Including Fixed Charges 46,450 42,826 41,303 47,886 52,137 42,691 42,204 48,258 Income Taxes 27,404 1,415 (2,007 ) 12,554 26,172 3,292 (2,871 ) 10,352 Energy and Other Taxes 1,027 560 838 1,195 1,420 854 806 951 Total Expenses 144,184 64,798 66,529 120,330 225,831 72,256 63,073 110,396 Other Income and Expense 836 1,079 1,189 727 760 1,670 1,010 404 Net Income $ 44,418 $ 5,043 $ (3,315 ) $ 22,899 $ 42,587 $ 5,226 $ (3,429 ) $ 22,194 NOTE: Because of the seasonal nature of our business, statements for the three-month periods are not indicative of the results for a full year.

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 7). 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 loan 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.

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	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 $ 9,778 $ 6,993 $ (47 ) $ 4,154 $ 12,570 Provision for Uncollectible Accounts for the Year Ended December 31, 2015 $ 6,601 $ 14,689 $ (235 ) $ 11,277 $ 9,778 Provision for Uncollectible Accounts for the Year Ended December 31, 2014 $ 4,553 $ 9,417 $ (102 ) $ 7,267 $ 6,601 (a) Recoveries of accounts previously written off and minor adjustments. (b) Uncollectible accounts written off.

SUMMARY OF SIGNIFICANT ACCOUN26

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
The Entity	The Entity - South Jersey Industries, Inc. (SJI) owns all of the outstanding common stock of South Jersey Gas Company (SJG). In our opinion, the financial statements reflect all normal and recurring adjustments needed to fairly present our financial position and operating results at the dates and for the periods presented.
Reclassifications	Certain reclassifications have been made to the prior period's balance sheets, as well as the prior period's long-term debt carrying value in Note 8, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the 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 8 to be adjusted.
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 our balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. 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 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 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 - We are subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 3 for a detailed discussion of our rate structure and regulatory actions. We maintain our accounts according to the BPU’s prescribed Uniform System of Accounts. We follow the accounting for regulated enterprises prescribed by the FASB 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 4 for a detailed discussion of regulatory assets and liabilities.
Operating Revenues	Operating Revenues - Gas revenues are recognized in the period the commodity is delivered to customers. For retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas delivered from the date of the last meter reading to the end of the month.
Revenue and Throughput-Based Taxes	Revenue and Throughput-Based Taxes - SJG collects certain revenue-based energy taxes from our 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 Uncollectible 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 balance sheets, and represents natural gas that will be utilized in the ordinary course of business.
Property, Plant & Equipment	Property, Plant & Equipment - For regulatory purposes, utility plant is stated at original cost, which may be different than our cost if the assets were acquired from another regulated entity. The cost of adding, replacing and renewing property is charged to the appropriate plant account.
Asset Retirement Obligations	Asset Retirement Obligations - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations we have to cut and cap our 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.
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.
Capitalized Interest	Capitalized Interest - We capitalize interest on construction at the rate of return on rate base utilized by the BPU to set rates in our last base rate proceeding. For our accelerated infrastructure programs, we capitalize interest on construction at a rate prescribed by the programs (see Note 3). Capitalized interest is included in Utility Plant on the balance sheets. Interest Charges are presented net of capitalized interest on the statements of income. We capitalized interest of $5.3 million in 2016 , $2.8 million in 2015 and $4.4 million in 2014 . The increase in 2016 represents the interest on the Company's investment in Utility Plant under the BPU-approved AIRP program. Under the AIRP, qualified capital expenditures continued to accrue interest on construction until such projects were rolled into customer rates and recovery of the expenditures commenced.
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. For the years ended 2016 , 2015 and 2014 , no significant impairments were identified.
Derivative Instruments	Derivative Instruments - SJG uses a variety of derivative instruments to limit its exposure to market risk in accordance with strict guidelines (see Note 14). 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 balance sheets. The costs or benefits of these short-term contracts are recoverable through SJG’s Basic Gas Supply Service (BGSS) clause, subject to BPU approval. As a result, the net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the balance sheets. SJG has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives-Other on the balance sheets. The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates. Subject to BPU approval, the market value upon termination of these interest rate derivatives can be recovered in rates and, therefore, these unrealized losses have been included in Other Regulatory Assets in the balance sheets.
Income Taxes	Income Taxes - Deferred income taxes are provided for all significant temporary differences between the book and taxable basis of assets and liabilities in accordance with FASB ASC Topic 740 – “Income Taxes” (See Note 6). 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.
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.
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 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 service providers 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 beginning after December 15, 2015 and interim periods within those annual periods, 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 "The Entity" 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.
Stock Based Compensation Plans	Officers and other key employees of SJG participate in the plans of SJI. Performance-based restricted shares vest over a three -year period and are subject to SJI achieving certain market and earnings-based performance targets which can cause the actual amount of shares that ultimately vest to range from 0% to 200% of the original share units granted. Beginning in 2015, SJI grants time-based shares of restricted stock, one-third of which vest annually over a three -year period and is limited to 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, payment is solely contingent upon the service requirement being met in years two and three of the grant. In 2016 and 2015, SJG Officers and other key employees were granted 9,965 and 7,878 shares of time-based restricted stock, respectively. 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 include pre-defined EGR and ROE goals to measure performance. Beginning in 2016, performance targets included 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. We are allocated a portion of SJI's compensation cost during the vesting period. We accrue a liability and record compensation cost over the requisite three -year service period based on the grant date fair value as described above for each type of grant. Upon vesting, we make a cash payment to SJI equal to the amounts accrued as compensation cost during the vesting period. Since the inception of the plans, our expense recognition policy has been consistent with the expense recognition policy at SJI.
Fair Value	(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. (C) Derivatives – Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. 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.

SUMMARY OF SIGNIFICANT ACCOUN27

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Schedule of Utility Plant balances	Utility Plant balances as of December 31, 2016 and 2015 were comprised of the following (in thousands): 2016 2015 Utility Plant: Production Plant $ 296 $ 296 Storage Plant 60,661 20,872 Transmission Plant 257,169 252,934 Distribution Plant 1,871,703 1,702,148 General Plant 169,464 163,420 Other Plant 1,855 1,855 Utility Plant in Service 2,361,148 2,141,525 Construction Work in Progress 62,986 69,714 Total Utility Plant $ 2,424,134 $ 2,211,239
Asset Retirement Obligation Activity	ARO activity during 2016 and 2015 was as follows (in thousands): 2016 2015 ARO as of January 1, $ 57,219 $ 41,976 Accretion 1,908 1,658 Additions 1,098 621 Settlements (1,551 ) (1,110 ) Revisions in Estimated Cash Flows * — 14,074 ARO as of December 31, $ 58,674 $ 57,219 * The revision in estimated cash flows in 2015 reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.

STOCK-BASED COMPENSATION PLANS

STOCK-BASED COMPENSATION PLANS (Tables)	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of the SJI nonvested restricted stock awards pertaining to SJG outstanding and the assumptions used to estimate the fair value of the awards	The following table summarizes the SJI nonvested restricted stock awards pertaining to SJG outstanding at December 31, 2016 , and the assumptions used to estimate the fair value of the awards: Grant Date Shares Outstanding Fair Value Per Share Expected Volatility Risk-Free Interest Rate 2015 - TSR 6,884 $ 26.31 16.0 % 1.10 % 2015 - EPS, ROE, Time 15,211 $ 29.47 n/a n/a 2016 - TSR 11,472 $ 22.53 18.1 % 1.31 % 2016 - CEGR, Time 21,305 $ 23.52 n/a n/a
Summary of the information regarding restricted stock award activity excluding accrued dividend equivalents	The following table summarizes information regarding restricted stock award activity during 2016 , excluding accrued dividend equivalents: Shares Weighted Average Grant Date Fair Value Nonvested Shares Outstanding, January 1, 2016 46,475 $ 26.67 Granted 33,218 $ 23.17 Vested* (21,995 ) $ 24.88 Cancelled/Forfeited** (2,826 ) $ 25.89 Nonvested Shares Outstanding, December 31, 2016 54,872 $ 25.31 * Based on performance information available at the filing of this report, management expects to award 5,593 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.

REGULATORY ASSETS AND LIABILI29

REGULATORY ASSETS AND LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets	Regulatory Assets at December 31 consisted of the following items (in thousands): 2016 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 at December 31 consisted of the following items (in thousands): 2016 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

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Summary of related party transactions	A summary of these related party transactions, excluding pass-through items, included in Operating Revenues were as follows (in thousands): 2016 2015 2014 Operating Revenues/Affiliates: SJRG $ 6,934 $ 5,342 $ 959 Marina 386 602 1,083 Other — 5 — Total Operating Revenues/Affiliates $ 7,320 $ 5,949 $ 2,042 Related party transactions, excluding pass-through items, included in Operating Expenses were as follows (in thousands): 2016 2015 2014 Costs of Sales/Affiliates (Excluding depreciation): SJRG $ 16,306 $ 26,090 $ 15,265 Derivative Losses/ (Gains) (See Note 1): SJRG $ — $ 64 $ (1,582 ) Operations Expense/Affiliates: SJI $ 20,296 $ 14,088 $ 14,110 Millennium 2,803 2,746 2,668 Other (198 ) (412 ) (434 ) Total Operations Expense/Affiliates $ 22,901 $ 16,422 $ 16,344

INCOME TAXES AND CREDITS (Table

INCOME TAXES AND CREDITS (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Schedule of 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 $ 37,944 $ 36,233 $ 35,482 Increase (Decrease) Resulting from: State Income Taxes 4,096 4,584 1,935 Amortization of Investment Tax Credits — (149 ) (211 ) ESOP Dividend (1,170 ) (1,168 ) (1,109 ) AFUDC (900 ) (1,109 ) (1,481 ) Research and Development Credits (613 ) (1,400 ) — Other - Net 9 (46 ) 279 Total Income Tax Expense $ 39,366 $ 36,945 $ 34,895
Schedule of components of provision for income taxes	The provision for Income Taxes is comprised of the following (in thousands): 2016 2015 2014 Current: Federal $ — $ — $ 60 State (1,614 ) (2,203 ) 2,642 Total Current (1,614 ) (2,203 ) 2,702 Deferred: Federal 33,064 30,042 32,069 State 7,916 9,255 335 Total Deferred 40,980 39,297 32,404 Investment Tax Credits — (149 ) (211 ) Total Income Tax Expense $ 39,366 $ 36,945 $ 34,895
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 liabilities at December 31 (in thousands): 2016 2015 Deferred Tax Assets: Net Operating Loss and Tax Credits $ 102,290 $ 64,978 Deferred State tax 24,574 20,825 Provision for Uncollectibles 5,170 4,030 Pension & Other Post Retirement Benefits 17,264 28,464 Deferred Revenues 7,696 4,844 Other 3,573 3,985 Total Deferred Tax Assets $ 160,567 $ 127,126 Deferred Tax Liabilities: Book Versus Tax Basis of Property $ 532,330 $ 480,682 Deferred Fuel Costs - Net 2,052 3,998 Environmental Remediation 33,573 20,408 Deferred Regulatory Costs 1,554 566 Deferred Pension & Other Post Retirement Benefits 34,432 42,216 Budget Billing - Customer Accounts 3,347 830 Section 461 Prepayments 1,147 1,017 Conservation Incentive Program 11,846 1,132 Other 9,694 8,951 Total Deferred Tax Liabilities $ 629,975 $ 559,800 Deferred Tax Liability - Net $ 469,408 $ 432,674
Reconciliation of unrecognized tax benefits	A reconciliation of unrecognized tax benefits is as follows (in thousands): 2016 2015 2014 Balance at January 1, $ 559 $ 552 $ 547 Increase as a result of tax position taken in prior years 802 7 5 Balance at December 31, $ 1,361 $ 559 $ 552

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Schedule of long-term debt	A schedule of our long-term debt as of December 31, including current maturities, is as follows (in thousands): 2016 2015 Long-Term Debt (A): First Mortgage Bonds: (B) 5.437 % Series due 2016 (C) — 10,000 4.60 % Series due 2016 (C) — 17,000 4.657 % Series due 2017 15,000 15,000 7.97 % Series due 2018 10,000 10,000 7.125 % Series due 2018 20,000 20,000 5.587 % Series due 2019 10,000 10,000 3.00 % Series due 2024 (D) 50,000 50,000 3.03 % Series due 2024 (E) 35,000 35,000 3.63 % Series due 2025 (F) 8,182 9,091 4.84 % Series due 2026 (G) 15,000 15,000 4.93 % Series due 2026 (H) 45,000 45,000 4.03 % Series due 2027 45,000 45,000 4.01 % Series due 2030 (I) 50,000 50,000 4.23 % Series due 2030 30,000 30,000 3.74 % Series due 2032 35,000 35,000 5.55 % Series due 2033 32,000 32,000 6.213 % Series due 2034 10,000 10,000 5.45 % Series due 2035 10,000 10,000 Series A 2006 Tax-Exempt First Mortgage Bonds Variable Rate, due 2036 (J) 24,900 24,900 Variable Rate Bank Term Facility, due 2017 (K) 200,000 139,000 Total Long-Term Debt Outstanding (L) 645,082 611,991 Less Current Maturities (215,909 ) (27,909 ) Long-Term Debt (L) $ 429,173 $ 584,082 (A) Long-term debt maturities for the succeeding five years are as follows (in thousands): 2017, $215,909 ; 2018, $ 38,909 ; 2019, $18,909 ; 2020, $17,909 ; 2021, $27,909 . (B) Our 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 17). (C) In July 2016, SJG retired $17.0 million aggregate principal amount of 4.6% Medium Term Notes (MTN's) at maturity. In August 2016, SJG retired $10.0 million aggregate principal amount 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 toward the principal amount of 3.63% MTN's annually, 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 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 is $200.0 million , which is classified in current portion of long-term debt on the balance sheets as it is due within one year. In January 2017, this term facility was paid in full (see Note 17). (L) Total Long-Term Debt in the table above does not include unamortized debt issuance costs of $6.0 million and $6.6 million for the years ended December 31, 2016 and 2015, respectively, which were reclassified to Long-Term Debt on the balance sheets to conform to ASU 2015-03 (see Note 1).

LINES OF CREDIT (Tables)

LINES OF CREDIT (Tables)	12 Months Ended
	Dec. 31, 2016
Line of Credit Facility [Abstract]
Schedule of credit facilities and available liquidity	Credit facilities and available liquidity as of December 31, 2016 were as follows (in thousands): Total Facility Usage Available Liquidity Expiration Date Commercial Paper Program/ Revolving Credit Facility $ 200,000 $ 105,100 (A) $ 94,900 May 2018 Uncommitted Bank Lines 10,000 — 10,000 August 2017 Total $ 210,000 $ 105,100 $ 104,900 (A) Includes letters of credit outstanding in the amount of $ 0.8 million .

PENSION AND OTHER POSTRETIREM34

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 Other Postretirement Benefits 2016 2015 2014 2016 2015 2014 Service Cost $ 4,144 $ 4,430 $ 3,697 $ 576 $ 726 $ 585 Interest Cost 10,292 9,357 8,952 2,120 2,406 2,297 Expected Return on Plan Assets (11,029 ) (11,914 ) (10,818 ) (2,823 ) (2,708 ) (2,467 ) Amortization: Prior Service Cost (Credits) 203 203 177 (257 ) 499 133 Actuarial Loss 7,975 8,969 4,864 945 1,107 770 Net Periodic Benefit Cost 11,585 11,045 6,872 561 2,030 1,318 Capitalized Benefit Costs (4,645 ) (4,805 ) (3,047 ) (277 ) (1,043 ) (722 ) Affiliate SERP Allocations (1,960 ) (1,688 ) (1,313 ) — — — Deferred Benefit Costs (644 ) (1,007 ) — — (256 ) — Total Net Periodic Benefit Expense $ 4,336 $ 3,545 $ 2,512 $ 284 $ 731 $ 596
Activity within Regulatory Asset and Accumulated Other Comprehensive 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 $ 23,170 $ — Amounts Arising during the Period: Net Actuarial (Gains)/Losses (463 ) (3,155 ) 184 — Prior Service Cost — (499 ) — — Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (6,079 ) (1,107 ) (2,891 ) — Prior Service Cost (203 ) (7,755 ) — — Balance at December 31, 2015 64,432 15,347 20,463 — Amounts Arising during the Period: Net Actuarial Loss 9,706 2,584 6,129 — Prior Service Credit — 257 — — Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (5,485 ) (945 ) (2,490 ) — Prior Service Cost (203 ) — — — Balance at December 31, 2016 $ 68,450 $ 17,243 $ 24,102 $ —
Estimated costs that will be amortized from Regulatory Assets	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 Loss	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 Net Actuarial Loss $ 2,378 $ —
Reconciliation of the plants' benefit obligations, fair value, funded status and amounts recognized	A reconciliation of the plans’ benefit obligations, fair value of plan assets, funded status and amounts recognized in our balance sheets follows (in thousands): Other Pension Benefits Postretirement Benefits 2016 2015 2016 2015 Change in Benefit Obligations : Benefit Obligation at Beginning of Year $ 213,660 $ 221,605 $ 46,518 $ 60,670 Service Cost 4,144 4,430 576 726 Interest Cost 10,292 9,357 2,120 2,406 Actuarial Loss (Gain) 17,463 (13,107 ) 2,292 (6,257 ) Retiree Contributions — — 70 608 Plan Amendments — — — (7,755 ) Benefits Paid (9,203 ) (8,625 ) (3,027 ) (3,880 ) Benefit Obligation at End of Year $ 236,356 $ 213,660 $ 48,549 $ 46,518 Change in Plan Assets: Fair Value of Plan Assets at Beginning of Year $ 149,032 $ 144,568 $ 43,428 $ 40,951 Actual Return on Plan Assets 12,656 (913 ) 2,531 (395 ) Employer Contributions 2,244 14,002 2,946 6,144 Retiree Contributions — — 70 608 Benefits Paid (9,203 ) (8,625 ) (3,027 ) (3,880 ) Fair Value of Plan Assets at End of Year $ 154,729 $ 149,032 $ 45,948 $ 43,428 Funded Status at End of Year : Accrued Net Benefit Cost at End of Year $ (81,627 ) $ (64,628 ) $ (2,601 ) $ (3,090 ) Amounts Recognized in the Statement of Financial Position Consist of: Current Liabilities $ (2,428 ) $ (2,227 ) $ — $ — Noncurrent Liabilities (79,199 ) (62,401 ) (2,601 ) (3,090 ) Net Amount Recognized at End of Year $ (81,627 ) $ (64,628 ) $ (2,601 ) $ (3,090 ) 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 Net Amount Recognized at End of Year $ 68,450 $ 64,432 $ 17,243 $ 15,347 Amounts Recognized in Accumulated Other Comprehensive Loss Consist of: Net Actuarial Loss $ 24,102 $ 20,463 $ — $ —
Schedule of 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 SJG’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) 13,372 — 13,372 $ — Common/Collective Trust Funds - International (a) 7,796 — 7,796 — Fixed Income: Common/Collective Trust Funds - Bonds (a) 12,167 — 12,167 — Other Types of Investments: Company Owned Life Insurance (c) 12,613 — 12,613 — Total $ 45,948 $ — $ 45,948 $ — Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015 Cash $ 26 $ 26 $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) 12,154 — 12,154 $ — Common/Collective Trust Funds - International (a) 7,471 — 7,471 — Mutual Fund - U.S. (b) 1,228 1,228 — — Mutual Funds - International (b) 922 922 — — Fixed Income: Common/Collective Trust Funds - Bonds (a) 11,852 — 11,852 — Mutual Funds - Bonds (b) 1,352 1,352 — — Other Types of Investments: Mutual Funds - REITS (b) 142 142 — — Company Owned Life Insurance (c) 8,281 — 8,281 — Total $ 43,428 $ 3,670 $ 39,758 $ — (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. The fair values of SJG’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 $ 52 $ 52 $ — $ — Common/Collective Trust Funds (a) 376 — 376 — STIF-Type Instrument (b) 1,168 — 1,168 — Equity securities: Common/Collective Trust Funds – U.S. (a) 42,369 — 42,369 — Common/Collective Trust Funds – International (a) 27,017 — 27,017 — U.S. Large-Cap (c) 14,523 14,523 — — U.S. Mid-Cap (c) 2,024 2,024 — — U.S. Small-Cap (c) — — — International (c) 2,727 2,727 — — Fixed Income: Common/Collective Trust Funds (a) 44,873 — 44,873 — Guaranteed Insurance Contract (d) 7,930 — — 7,930 Hedge Funds (e) — — — — Other types of investments: Private Equity Fund (f) 4,164 — — 4,164 Common/Collective Trust Fund – Real Estate (g) 7,506 — — 7,506 Total $ 154,729 $ 19,326 $ 115,803 $ 19,600 Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015 Cash / Cash Equivalents: Cash $ 28 $ 28 — $ — Common/Collective Trust Funds (a) 692 — 692 — STIF-Type Instrument (b) 1,096 — 1,096 — Equity securities: Common/Collective Trust Funds – U.S. (a) 41,976 — 41,976 — Common/Collective Trust Funds – International (a) 26,800 — 26,800 — U.S. Large-Cap (c) 11,535 11,535 — — U.S. Mid-Cap (c) 2,748 2,748 — — U.S. Small-Cap (c) 210 210 International (c) 1,367 1,367 — — Fixed Income: Common/Collective Trust Funds (a) 40,853 — 40,853 — Guaranteed Insurance Contract (d) 8,031 — — 8,031 Hedge Funds (e) 3,353 — — 3,353 Other types of investments: Private Equity Fund (f) 3,477 — — 3,477 Common/Collective Trust Fund – Real Estate (g) 6,866 — — 6,866 Total $ 149,032 $ 15,888 $ 111,417 $ 21,727 (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 the 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 which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 to 120 day lag and, therefore, the value reported herein represents the market value as of June or September 30, 2016 and 2015, 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 2 investments.
Changes in plan assets	Fair Value Measurement Using Significant Unobservable Inputs (Level 3) (In thousands) Guaranteed Insurance Contract Hedge Funds Private Equity Funds Real Estate Total Balance at January 1, 2015 $ 8,738 $ 3,469 $ 2,895 $ 5,987 $ 21,089 Actual return on plan assets: Relating to assets still held at the reporting date (26 ) (116 ) (223 ) 879 514 Relating to assets sold during the period 21 — 346 — 367 Purchases, Sales and Settlements (702 ) — 459 — (243 ) Balance at December 31, 2015 $ 8,031 $ 3,353 $ 3,477 $ 6,866 $ 21,727 Actual return on plan assets: Relating to assets still held at the reporting date 541 (13 ) (71 ) 640 1,097 Relating to assets sold during the period 12 — 200 — 212 Purchases, Sales and Settlements (654 ) (3,340 ) 558 — (3,436 ) Balance at December 31, 2016 $ 7,930 $ — $ 4,164 $ 7,506 $ 19,600
Future benefit payments	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 $ 10,339 $ 3,600 2018 $ 10,619 $ 3,577 2019 $ 11,472 $ 3,677 2020 $ 11,921 $ 3,790 2021 $ 12,481 $ 3,811 2022 - 2026 $ 73,847 $ 18,131

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 accrued and expended for environmental remediation at December 31 (in thousands): 2016 2015 Beginning of Year $ 123,194 $ 124,308 Accruals 61,933 18,747 Expenditures (32,080 ) (19,861 ) End of Year $ 153,047 $ 123,194

FAIR VALUE OF FINANCIAL ASSET36

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair value of assets and liabilities	For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands): As of December 31, 2016 Total Level 1 Level 2 Level 3 Assets Derivatives – Energy Related Assets (B) 5,807 4,767 — 1,040 $ 5,807 $ 4,767 $ — $ 1,040 Liabilities Derivatives – Energy Related Liabilities (B) $ 1,372 $ 6 $ 1,252 $ 114 Derivatives – Other (C) 7,365 — 7,365 — $ 8,737 $ 6 $ 8,617 $ 114 As of December 31, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 8,788 $ 1,722 $ 7,066 $ — Derivatives – Energy Related Assets (B) 1,141 398 144 599 $ 9,929 $ 2,120 $ 7,210 $ 599 Liabilities Derivatives – Energy Related Liabilities (B) $ 5,840 $ 5,424 $ — $ 416 Derivatives – Other (C) 7,631 — 7,631 — $ 13,471 $ 5,424 $ 7,631 $ 416 (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. (C) Derivatives – Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.
Quantitative information regarding significant unobservable inputs in Level 3 fair value measurements	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands): Type Fair Value at December 31, 2016 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $1,040 $114 Discounted Cash Flow Forward price (per dt) $3.25 - $6.33 Type Fair Value at December 31, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $599 $416 Discounted Cash Flow Forward price (per dt) $1.18 - $5.21
Fair value measurements of Derivatives - Energy Related Assets and Liabilities	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 $ 183 Other Changes in Fair Value from Continuing and New Contracts, Net 926 Settlements (183 ) Balance at December 31, 2016 $ 926 Year Ended December 31, 2015 Balance at January 1, 2015 $ — Other Changes in Fair Value from Continuing and New Contracts, Net 183 Settlements — Balance at December 31, 2015 $ 183

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of active interest rate swaps	As of December 31, 2016 , SJG’s active interest rate swaps were as follows: Notional Amount Fixed Interest Rate Start Date Maturity Type of Debt Obligor $ 12,500,000 3.53 % 12/1/2006 2/1/2036 Tax-exempt SJG $ 12,500,000 3.43 % 12/1/2006 2/1/2036 Tax-exempt SJG
Fair value of derivative instruments	The fair values of all derivative instruments, as reflected in the balance sheets as of December 31, 2016 and 2015 , 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 $ 5,434 $ 1,372 $ 1,077 $ 5,489 Derivatives – Energy Related – Non-Current 373 — 64 351 Interest rate contracts: Derivatives – Other Current 386 — Derivatives – Other Noncurrent — 6,979 — 7,631 Total derivatives not designated as hedging instruments under GAAP $ 5,807 $ 8,737 $ 1,141 $ 13,471
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 $ 5,807 $ — $ 5,807 $ (6 ) (A) $ (3,587 ) $ 2,214 Derivatives - Energy Related Liabilities $ (1,372 ) $ — $ (1,372 ) $ 6 (B) $ — $ (1,366 ) Derivatives - Other $ (7,365 ) $ — $ (7,365 ) $ — $ — $ (7,365 ) As of December 31, 2015 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets $ 1,141 $ — $ 1,141 $ (399 ) (A) $ — $ 742 Derivatives - Energy Related Liabilities $ (5,840 ) $ — $ (5,840 ) $ 399 (B) $ 5,025 $ (416 ) Derivatives - Other $ (7,631 ) $ — $ (7,631 ) $ — $ — $ (7,631 ) (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 derivative instruments on the statements of income	The effect of derivative instruments on the statements of income for 2016 , 2015 and 2014 are as follows (in thousands): Year ended December 31, Derivatives in Cash Flow Hedging Relationships 2016 2015 2014 Interest Rate Contracts: Losses reclassified from accumulated OCI into income (a) $ (46 ) $ (46 ) $ (46 ) (a) Included in Interest Charges

ACCUMULATED OTHER COMPREHENSI38

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Summary of changes in accumulated other comprehensive loss	The following tables summarizes the changes in accumulated other comprehensive loss (AOCL) for the years ended December 31, 2016 and 2015 , respectively (in thousands): Postretirement Liability Adjustment Unrealized Gain (Loss) on Derivatives-Other Unrealized Gain (Loss) on Available-for-Sale Securities Total Balance at January 1, 2016 (a) $ (12,220 ) $ (544 ) $ (98 ) $ (12,862 ) Other comprehensive income before reclassifications (3,687 ) — 323 (3,364 ) Amounts reclassified from AOCL (b) 1,490 27 (225 ) 1,292 Net current period other comprehensive income (2,197 ) 27 98 (2,072 ) Balance at December 31, 2016 (a) $ (14,417 ) $ (517 ) $ — $ (14,934 ) Postretirement Liability Adjustment Unrealized Gain (Loss) on Derivatives-Other Unrealized Gain (Loss) on Available-for-Sale Securities Total Balance at January 1, 2015 (a) $ (13,837 ) $ (567 ) $ (75 ) $ (14,479 ) Other comprehensive income before reclassifications (110 ) — (76 ) (186 ) Amounts reclassified from AOCL (b) 1,727 23 53 1,803 Net current period other comprehensive income 1,617 23 (23 ) 1,617 Balance at December 31, 2015 (a) $ (12,220 ) $ (544 ) $ (98 ) $ (12,862 ) (a) Determined using a combined statutory tax rate of 40% in 2016 and 2015 . (b) See table below.
Reclassifications out of AOCL	The reclassifications out of AOCL for the years ended December 31, 2016 and 2015 is as follows (in thousands): Components of AOCL Amounts Reclassified from AOCL Affected Line Item in the Statements of Income For the Year Ended For the Year Ended Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges $ 46 $ 46 Interest Charges Income Taxes (19 ) (23 ) Income Taxes (a) $ 27 $ 23 Unrealized Loss(Gain) on Available-for-Sale Securities (377 ) 90 Other Income & Expense Income Taxes 152 (37 ) Income Taxes (a) $ (225 ) $ 53 Actuarial Loss on Postretirement Benefits 2,490 2,891 Operating Expenses: Operations Income Taxes (1,000 ) (1,164 ) Income Taxes (a) $ 1,490 $ 1,727 Losses from reclassifications for the period net of tax $ 1,292 $ 1,803 (a) Determined using a combined statutory tax rate of 40% in 2016 and 2015 .

QUARTERLY RESULTS OF OPERATIO39

QUARTERLY RESULTS OF OPERATIONS - UNAUDITED (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	The summarized quarterly results of our operations are as follows (in thousands): 2016 Quarter Ended 2015 Quarter Ended March 31 June 30 Sept. 30 Dec. 31 March 31 June 30 Sept. 30 Dec. 31 Operating Revenues $ 187,766 $ 68,762 $ 62,025 $ 142,502 $ 267,658 $ 75,812 $ 58,634 $ 132,186 Expenses: Cost of Sales (excluding depreciation) 69,303 19,997 26,395 58,695 146,102 25,419 22,934 50,835 Operations and Maintenance Including Fixed Charges 46,450 42,826 41,303 47,886 52,137 42,691 42,204 48,258 Income Taxes 27,404 1,415 (2,007 ) 12,554 26,172 3,292 (2,871 ) 10,352 Energy and Other Taxes 1,027 560 838 1,195 1,420 854 806 951 Total Expenses 144,184 64,798 66,529 120,330 225,831 72,256 63,073 110,396 Other Income and Expense 836 1,079 1,189 727 760 1,670 1,010 404 Net Income $ 44,418 $ 5,043 $ (3,315 ) $ 22,899 $ 42,587 $ 5,226 $ (3,429 ) $ 22,194

SUMMARY OF SIGNIFICANT ACCOUN40

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) - USD ($)	Oct. 01, 2014	Sep. 30, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
Equity investment impairments			$ 0	$ 0	$ 0
PUA included in both utility revenue and cost of sales			1,100,000	1,200,000	1,100,000
Utility Plant:
Production Plant			296,000	296,000
Storage Plant			60,661,000	20,872,000
Transmission Plant			257,169,000	252,934,000
Distribution Plant			1,871,703,000	1,702,148,000
General Plant			169,464,000	163,420,000
Other Plant			1,855,000	1,855,000
Utility Plant in Service			2,361,148,000	2,141,525,000
Construction Work in Progress			62,986,000	69,714,000
Total Utility Plant			2,424,134,000	2,211,239,000
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO as of January 1,			57,219,000	41,976,000
Accretion			1,908,000	1,658,000
Additions			1,098,000	621,000
Settlements			(1,551,000)	(1,110,000)
Revisions in Estimated Cash Flows			0	14,074,000
ARO as of December 31,			$ 58,674,000	$ 57,219,000	$ 41,976,000
Composite annual rate for all depreciable utility property			2.20%	2.20%	2.20%
Composite depreciation rate	2.10%	2.40%
Interest capitalized			$ 5,300,000	$ 2,800,000	$ 4,400,000

STOCK-BASED COMPENSATION PLAN41

STOCK-BASED COMPENSATION PLANS (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Service requirement period	3 years
Shares granted (in shares)	33,218
Shares Outstanding (in shares)	46,475	46,475		54,872
Fair Value Per Share (in USD per share)	$ 26.67	$ 26.67		$ 25.31
Expected volatility, measurement period	3 years
Cost of restricted stock awards	$ 0.6	$ 0.3	$ 0.2
Amount to be capitalized to Utility Plant	50.00%	50.00%	50.00%
Unrecognized compensation cost of awards granted under the plan				$ 0.7
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	1 year 8 months 12 days
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)	46,475
Shares granted (in shares)	33,218
Vested (in shares)	(21,995)
Cancelled/Forfeited (in shares)	(2,826)
Nonvested Shares Outstanding, ending balance (in shares)	54,872	46,475
Weighted Average Grant Date Fair Value
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, beginning balance (in USD per share)	$ 26.67
Weighted Average Grant Date Fair Value, Granted (in USD per share)	23.17
Weighted Average Grant Date Fair Value, Vested (in USD per share)	24.88
Weighted Average Grant Date Fair Value, Cancelled/Forfeited (in USD per share)	25.89
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in USD per share)	$ 25.31	$ 26.67
Cash payments to SJI relating to stock awards	$ 0.2	$ 0.2	$ 0.4
Officers and key employees
Weighted Average Grant Date Fair Value
Expected number of shares to be awarded				5,593
Number of shares awarded during the period	2,610
Market value of shares awarded	$ 0.1
2015 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	6,884			6,884
Fair Value Per Share (in USD per share)	$ 26.31			$ 26.31
Expected Volatility	16.00%
Risk-Free Interest Rate	1.10%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, ending balance (in shares)	6,884
Weighted Average Grant Date Fair Value
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in USD per share)	$ 26.31
2015 - EPS, ROE, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	15,211			15,211
Fair Value Per Share (in USD per share)	$ 29.47			$ 29.47
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, ending balance (in shares)	15,211
Weighted Average Grant Date Fair Value
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in USD per share)	$ 29.47
2016 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	11,472			11,472
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)	11,472
Weighted Average Grant Date Fair Value
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in USD per share)	$ 22.53
2016 - CEGR, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	21,305			21,305
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)	21,305
Weighted Average Grant Date Fair Value
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in USD per share)	$ 23.52
Performance shares
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Vesting period of shares	3 years
Performance shares | 2012 and 2013 grant dates
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Vesting period of shares	3 years
Weighted Average Grant Date Fair Value
Number of shares awarded during the period	0	0
Restricted stock
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Vesting period of shares	3 years	3 years
Amount of payout limit for one-third of the time-based shares of restricted stock	100.00%
Minimum return on equity requirement	7.00%	7.00%
Shares granted (in shares)	9,965	7,878
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Shares granted (in shares)	9,965	7,878
Restricted stock | Tranche Two
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Service requirement period		2 years
Restricted stock | Tranche Three
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Service requirement period		3 years
Minimum
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted	0.00%
Maximum
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted	200.00%

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 ($)	Feb. 29, 2016USD ($)	Sep. 30, 2015USD ($)	Aug. 31, 2015USD ($)	Jul. 31, 2015USD ($)	Jun. 30, 2015USD ($)	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 ($)	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)	Jan. 31, 2016USD ($)	Apr. 30, 2015USD ($)	Jan. 31, 2015USD ($)	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																			$ 35,300
Investment amount of SHARP															$ 103,500			$ 280,000					$ 36,600
Term of SHARP															3 years			7 years
Number of gas manufacturing plants (in sites) | site																					12
Regulatory assets																					$ 410,746			$ 323,434
Number of customers purchasing gas commodities from a competitor | customer																					33,467
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Requested increase (decrease) in gas cost recoveries							$ (800)
Approved increase (decrease) in gas cost recoveries				$ (1,600)
Approved revenue increase (decrease)		$ (7,900)							$ (7,900)
Regulatory assets																					$ 219			496
Environmental restoration costs expended net
Schedule of Capitalization [Line Items]
Regulatory assets																					71,997			42,032
Other regulatory assets, deferred pipeline integrity costs
Schedule of Capitalization [Line Items]
Regulatory assets																					4,000			2,700
Storm Hardening and Reliability Program | Building
Schedule of Capitalization [Line Items]
SHARP investment																						$ 33,700
New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Approved increase (decrease) in gas cost recoveries				11,000
Authorized replacement investments (up to)				302,500
Roll of AIRP investments into base rates				$ 80,200
Statewide budget for all the State's gas utilities					$ 56,000
New Jersey Board of Public Utilities | South Jersey Gas Company
Schedule of Capitalization [Line Items]
Statewide budget for all the State's gas utilities					5,600
Resulting increase (decrease) to USF recoveries from statewide budget	$ 1,100
New Jersey Board of Public Utilities | Storm Hardening and Reliability Program
Schedule of Capitalization [Line Items]
Requested increase (decrease) in gas cost recoveries								$ 4,300
Approved increase (decrease) in gas cost recoveries					3,900
Accelerated Infrastructure Replacement Program
Schedule of Capitalization [Line Items]
Approved base rate increase														$ 7,500
Requested increase (decrease) in gas cost recoveries									13,000
Amount of AIRP									$ 500,000
Investments to be rolled to base rate														69,900
Extension period of AIRP, requested and then received		7 years		5 years
Basic Gas Supply Service
Schedule of Capitalization [Line Items]
Bill credit																					$ 10,000				$ 20,000				$ 11,200
Requested increase (decrease) in recoveries																	$ 27,000
Requested percentage of increase in gas cost recoveries																	9.30%
Approved increase (decrease) in gas recoveries														27,000
Requested increase (decrease) in gas cost recoveries													$ (28,400)
Approved increase (decrease) in gas cost recoveries										$ (28,400)
Basic Gas Supply Service | New Jersey Board of Public Utilities
Schedule of Capitalization [Line Items]
Requested increase (decrease) in gas cost recoveries							(47,100)
Approved increase (decrease) in gas cost recoveries					$ (47,100)
Conservation Incentive Program
Schedule of Capitalization [Line Items]
Requested increase (decrease) in gas cost recoveries							46,500						(11,300)				$ (21,800)
Conservation Incentive Program | Non weather
Schedule of Capitalization [Line Items]
Requested increase (decrease) in gas cost recoveries							9,900						(8,800)				4,200
Conservation Incentive Program | Weather
Schedule of Capitalization [Line Items]
Requested increase (decrease) in gas cost recoveries							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]
Requested increase (decrease) in recoveries																										$ 4,000
Approved increase (decrease) in gas recoveries										4,000
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Requested increase (decrease) in recoveries																	$ 1,400										$ 56,000
Approved increase (decrease) in gas recoveries											$ 2,600			2,200
Requested increase (decrease) in gas cost recoveries													(7,600)
Approved budget											$ 36,300									$ 17,000										$ 24,000
Period of time in which energy efficiency measures will be installed																				2 years
Approved extension of EEPs											2 years
Societal Benefits Clause
Schedule of Capitalization [Line Items]
Requested increase (decrease) in gas cost recoveries						$ 16,000						$ (5,000)				$ (25,700)
Remediation Adjustment Clause
Schedule of Capitalization [Line Items]
Number of gas manufacturing plants (in sites) | site																					12
Amortization period to recover costs																					7 years
Amounts recovered through rates																								112,700
Remediation Adjustment Clause | Environmental restoration costs expended net
Schedule of Capitalization [Line Items]
Regulatory assets																					$ 72,000			$ 42,000
New Jersey Clean Energy Program
Schedule of Capitalization [Line Items]
Statewide budget							345,000						345,000									345,000	345,000					$ 345,000		345,000
Statewide budget, entity's responsibility							14,600						14,600									14,600	14,600					14,500		$ 14,500
Universal Service Fund
Schedule of Capitalization [Line Items]
Approved increase (decrease) in gas recoveries										5,200				7,900
Statewide budget										46,400				71,800
Proposed increase (decrease) to statewide gas revenues							56,000						(46,400)									56,000	(46,400)					19,900
Potential impact of proposed increase (decrease) to statewide gas revenues							$ 1,100						$ (3,400)									$ 1,100	$ (3,400)					$ 2,600
Resulting impact of proposed increase (decrease) to USF recoveries										$ (3,400)				$ 2,600

REGULATORY ASSETS AND LIABILI43

REGULATORY ASSETS AND LIABILITIES - Assets (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)siteasset	Dec. 31, 2014USD ($)	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 Restoration Costs
Regulatory Assets [Line Items]
Approved recoverable period	7 years
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
AFUDC Equity Related Deferrals
Regulatory Assets [Line Items]
Total Regulatory Assets		$ 1,000
Approved recoverable period		3 years

REGULATORY ASSETS AND LIABILI44

REGULATORY ASSETS AND 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 Gas Costs - Net
Regulatory Liabilities [Line Items]
Regulatory assets		0	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 Gas Costs - 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

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating Revenues/Affiliates:
Total Operating Revenues/Affiliates	$ 7,320	$ 5,949	$ 2,042
Derivative Losses/ (Gains)	3,000	9,100	(1,700)
Operations Expense/Affiliates:
Total Operations Expense/Affiliates	22,901	16,422	16,344
SJRG
Operating Revenues/Affiliates:
Total Operating Revenues/Affiliates	6,934	5,342	959
Cost of Sales/Affiliates (Excluding depreciation)	16,306	26,090	15,265
Derivative Losses/ (Gains)	0	64	(1,582)
Marina
Operating Revenues/Affiliates:
Total Operating Revenues/Affiliates	386	602	1,083
SJI
Operations Expense/Affiliates:
Total Operations Expense/Affiliates	20,296	14,088	14,110
Millennium
Operations Expense/Affiliates:
Total Operations Expense/Affiliates	2,803	2,746	2,668
Other
Operating Revenues/Affiliates:
Total Operating Revenues/Affiliates	0	5	0
Operations Expense/Affiliates:
Total Operations Expense/Affiliates	$ (198)	$ (412)	$ (434)

INCOME TAXES AND CREDITS (Detai

INCOME TAXES AND CREDITS (Details) - USD ($)	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
Income Tax Expense (Benefit), Continuing Operations, Income Tax Reconciliation [Abstract]
Tax at Statutory Rate									$ 37,944,000	$ 36,233,000	$ 35,482,000
Increase (Decrease) Resulting from:
State Income Taxes									4,096,000	4,584,000	1,935,000
Amortization of Investment Tax Credits									0	(149,000)	(211,000)
ESOP Dividend									(1,170,000)	(1,168,000)	(1,109,000)
AFUDC									(900,000)	(1,109,000)	(1,481,000)
Research and Development Credits									(613,000)	(1,400,000)	0
Other - Net									9,000	(46,000)	279,000
Total Income Tax Expense	$ 12,554,000	$ (2,007,000)	$ 1,415,000	$ 27,404,000	$ 10,352,000	$ (2,871,000)	$ 3,292,000	$ 26,172,000	39,366,000	36,945,000	34,895,000
Current:
Federal									0	0	60,000
State									(1,614,000)	(2,203,000)	2,642,000
Total Current									(1,614,000)	(2,203,000)	2,702,000
Deferred:
Federal									33,064,000	30,042,000	32,069,000
State									7,916,000	9,255,000	335,000
Total Deferred									40,980,000	39,297,000	32,404,000
Investment Tax Credits									0	(149,000)	(211,000)
Total Income Tax Expense	12,554,000	$ (2,007,000)	$ 1,415,000	27,404,000	10,352,000	$ (2,871,000)	$ 3,292,000	26,172,000	$ 39,366,000	36,945,000	34,895,000
Annual amortization rate of investment tax credits									3.00%
Deferred Tax Assets:
Net Operating Loss and Tax Credits	102,290,000				64,978,000				$ 102,290,000	64,978,000
Deferred State tax	24,574,000				20,825,000				24,574,000	20,825,000
Provision for Uncollectibles	5,170,000				4,030,000				5,170,000	4,030,000
Pension & Other Post Retirement Benefits	17,264,000				28,464,000				17,264,000	28,464,000
Deferred Revenues	7,696,000				4,844,000				7,696,000	4,844,000
Other	3,573,000				3,985,000				3,573,000	3,985,000
Total Deferred Tax Assets	160,567,000				127,126,000				160,567,000	127,126,000
Deferred Tax Liabilities:
Book Versus Tax Basis of Property	532,330,000				480,682,000				532,330,000	480,682,000
Deferred Fuel Costs - Net	2,052,000				3,998,000				2,052,000	3,998,000
Environmental Remediation	33,573,000				20,408,000				33,573,000	20,408,000
Deferred Regulatory Costs	1,554,000				566,000				1,554,000	566,000
Deferred Pension & Other Post Retirement Benefits	34,432,000				42,216,000				34,432,000	42,216,000
Budget Billing - Customer Accounts	3,347,000				830,000				3,347,000	830,000
Section 461 Prepayments	1,147,000				1,017,000				1,147,000	1,017,000
Conservation Incentive Program	11,846,000				1,132,000				11,846,000	1,132,000
Other	9,694,000				8,951,000				9,694,000	8,951,000
Total Deferred Tax Liabilities	629,975,000				559,800,000				629,975,000	559,800,000
Deferred Tax Liability - Net	469,408,000				432,674,000				469,408,000	432,674,000
Research and development credits	2,700,000								2,700,000
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1,				$ 559,000				$ 552,000	559,000	552,000	547,000
Increase as a result of tax position taken in prior years									802,000	7,000	5,000
Balance at December 31,	1,361,000				559,000				1,361,000	559,000	552,000
Accrued interest and penalties on unrecognized tax benefits	700,000				700,000				700,000	700,000	$ 700,000
Federal
Deferred Tax Liabilities:
Operating loss carryforwards	263,000,000				179,300,000				263,000,000	179,300,000
State
Deferred Tax Liabilities:
Operating loss carryforwards	80,200,000								80,200,000
SJI | Prepaid taxes
Deferred Tax Liabilities:
Income taxes due from parent company	$ 0				$ 0				$ 0	$ 0

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	Dec. 31, 2015
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding (L)				$ 645,082,000	$ 611,991,000
Less Current Maturities				(215,909,000)	(27,909,000)
Long-Term Debt (L)				429,173,000	584,082,000
Long-term Debt, Fiscal Year Maturity [Abstract]
2,017				215,909,000
2,018				38,909,000
2,019				18,909,000
2,020				17,909,000
2,021				27,909,000
Letter of credit provided				210,000,000
Debt issuance costs				$ 6,000,000	6,600,000
First Mortgage Bonds | Series Due 2016, 5.437%
Debt Instrument [Line Items]
Stated interest rate	5.437%			5.437%
Total Long-Term Debt Outstanding (L)				$ 0	10,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Retired debt	$ 10,000,000
First Mortgage Bonds | Series Due 2016, 4.60%
Debt Instrument [Line Items]
Stated interest rate				4.60%
Total Long-Term Debt Outstanding (L)				$ 0	17,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Retired debt		$ 17,000,000
First Mortgage Bonds | Series Due 2017, 4.657%
Debt Instrument [Line Items]
Stated interest rate				4.657%
Total Long-Term Debt Outstanding (L)				$ 15,000,000	15,000,000
First Mortgage Bonds | Series Due 2018, 7.97%
Debt Instrument [Line Items]
Stated interest rate				7.97%
Total Long-Term Debt Outstanding (L)				$ 10,000,000	10,000,000
First Mortgage Bonds | Series Due 2018, 7.125%
Debt Instrument [Line Items]
Stated interest rate				7.125%
Total Long-Term Debt Outstanding (L)				$ 20,000,000	20,000,000
First Mortgage Bonds | Series Due 2019, 5.587%
Debt Instrument [Line Items]
Stated interest rate				5.587%
Total Long-Term Debt Outstanding (L)				$ 10,000,000	10,000,000
First Mortgage Bonds | Series Due 2024, 3.00%
Debt Instrument [Line Items]
Stated interest rate				3.00%
Total Long-Term Debt Outstanding (L)				$ 50,000,000	50,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payments due				$ 10,000,000
First Mortgage Bonds | Series Due 2024, 3.03%
Debt Instrument [Line Items]
Stated interest rate				3.03%
Total Long-Term Debt Outstanding (L)				$ 35,000,000	35,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payments due				$ 7,000,000
First Mortgage Bonds | Series Due 2025, 3.63%
Debt Instrument [Line Items]
Stated interest rate				3.63%
Total Long-Term Debt Outstanding (L)				$ 8,182,000	9,091,000
First Mortgage Bonds | Series Due 2025, 3.63% | South Jersey Gas Company
Debt Instrument [Line Items]
Stated interest rate				3.63%
Less Current Maturities				$ (900,000)
Long-term Debt, Fiscal Year Maturity [Abstract]
Payment towards the principal				$ 900,000
First Mortgage Bonds | Series Due 2026, 4.84%
Debt Instrument [Line Items]
Stated interest rate				4.84%
Total Long-Term Debt Outstanding (L)				$ 15,000,000	15,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payments due				$ 2,500,000
First Mortgage Bonds | Series Due 2026, 4.93%
Debt Instrument [Line Items]
Stated interest rate				4.93%
Total Long-Term Debt Outstanding (L)				$ 45,000,000	45,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Annual payments due				$ 7,500,000
First Mortgage Bonds | Series Due 2027, 4.03%
Debt Instrument [Line Items]
Stated interest rate				4.03%
Total Long-Term Debt Outstanding (L)				$ 45,000,000	45,000,000
First Mortgage Bonds | Series Due 2030, 4.01%
Debt Instrument [Line Items]
Stated interest rate				4.01%
Total Long-Term Debt Outstanding (L)				$ 50,000,000	50,000,000
First Mortgage Bonds | Series Due 2030, 4.01% | South Jersey Gas Company
Debt Instrument [Line Items]
Stated interest rate				4.01%
Total Long-Term Debt Outstanding (L)				$ 50,000,000
First Mortgage Bonds | Series Due 2030, 4.23%
Debt Instrument [Line Items]
Stated interest rate				4.23%
Total Long-Term Debt Outstanding (L)				$ 30,000,000	30,000,000
First Mortgage Bonds | Series Due 2032, 3.74%
Debt Instrument [Line Items]
Stated interest rate				3.74%
Total Long-Term Debt Outstanding (L)				$ 35,000,000	35,000,000
First Mortgage Bonds | Series Due 2033, 5.55%
Debt Instrument [Line Items]
Stated interest rate				5.55%
Total Long-Term Debt Outstanding (L)				$ 32,000,000	32,000,000
First Mortgage Bonds | Series Due 2034, 6.213%
Debt Instrument [Line Items]
Stated interest rate				6.213%
Total Long-Term Debt Outstanding (L)				$ 10,000,000	10,000,000
First Mortgage Bonds | Series Due 2035, 5.45%
Debt Instrument [Line Items]
Stated interest rate				5.45%
Total Long-Term Debt Outstanding (L)				$ 10,000,000	10,000,000
First Mortgage Bonds | MTN, 4.01%, Due November 2018 and November 2019 | South Jersey Gas Company
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding (L)				8,000,000
First Mortgage Bonds | MTN, 4.01%, Due November 2025 | South Jersey Gas Company
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding (L)				2,000,000
First Mortgage Bonds | MTN, 4.01%, Due November 2026 | South Jersey Gas Company
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding (L)				3,000,000
First Mortgage Bonds | MTN, 4.01%, Due November 2027 | South Jersey Gas Company
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding (L)				8,000,000
First Mortgage Bonds | MTN, 4.01%, Due November 2028, November 2029 and November 2030 | South Jersey Gas Company
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding (L)				7,000,000
Bonds at variable rates | Series A 2006 Tax-Exempt First Mortgage Bonds, Variable Rate, due 2036
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding (L)				$ 24,900,000	24,900,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at end of period				0.74%
Loans Payable | Term Line of Credit
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding (L)				$ 200,000,000	139,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Letter of credit provided				200,000,000
Outstanding debt				$ 200,000,000	$ 139,000,000
Average interest rate			1.41%		1.17%
Additional issuance of long-term debt			$ 61,000,000
Medium-term Notes
Long-term Debt, Fiscal Year Maturity [Abstract]
Approved borrowing capacity					$ 400,000,000

FINANCIAL INSTRUMENTS (Details)

FINANCIAL INSTRUMENTS (Details)	1 Months Ended	12 Months Ended
	Jun. 30, 2015USD ($)term	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Schedule of Financial Instruments [Line Items]
Balance owed to counterparty		$ 32,000	$ 6,769,000
Carrying amount of long-term debt		645,082,000	611,991,000
Debt issuance costs		$ 6,000,000	6,600,000
Minimum
Schedule of Financial Instruments [Line Items]
Term of loans		5 years
Maximum
Schedule of Financial Instruments [Line Items]
Term of loans		10 years
Atlantic City Note Receivable
Schedule of Financial Instruments [Line Items]
Amount of advance to not-for profit organization	$ 10,000,000
Interest rate of note	1.00%
Term of loans	6 months
Optional additional term | term	2
Term of extension option	3 months
Unnamed counterparty
Schedule of Financial Instruments [Line Items]
Balance owed to counterparty		$ 3,600,000	6,700,000
Level 1
Schedule of Financial Instruments [Line Items]
Restricted investments held in escrow		32,200	32,200
Level 2
Schedule of Financial Instruments [Line Items]
Estimated fair value of long-term debt		673,100,000	657,400,000
Carrying amount of long-term debt		639,100,000	605,400,000
Level 2 | Financing receivable
Schedule of Financial Instruments [Line Items]
Carrying amount of loans		9,500,000	12,900,000
Imputed interest on long-term receivables		$ 900,000	$ 1,300,000

RETAINED EARNINGS (Details)

RETAINED EARNINGS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Equity [Abstract]
Amount of cash dividends declared to SJI	$ 0	$ 40,700,000
Cash dividends paid to SJI	0	40,700,000
Equity infusions from SJI	$ 65,000,000	$ 0	$ 25,000,000

LINES OF CREDIT (Details)

LINES OF CREDIT (Details)	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014
Line of Credit Facility [Line Items]
Total Facility	$ 210,000,000
Usage	105,100,000
Available Liquidity	$ 104,900,000
Financial covenant, ratio of indebtedness to consolidated total capitalization (not more than)	0.65
Average borrowings outstanding	$ 71,500,000	$ 118,100,000
Maximum amounts outstanding	$ 141,700,000	$ 162,300,000
Weighted average borrowing cost	0.97%	0.66%	0.45%
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
Letters of credit outstanding	800,000
Uncommitted Bank Lines
Line of Credit Facility [Line Items]
Total Facility	10,000,000
Usage	0
Available Liquidity	10,000,000
South Jersey Gas Commercial Paper Program
Line of Credit Facility [Line Items]
Total Facility	$ 200,000,000
Fixed maturities of notes	270 days

PENSION AND OTHER POSTRETIREM51

PENSION AND OTHER POSTRETIREMENT BENEFITS (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	50.40%
Pension Benefits
Net periodic benefit cost [Abstract]
Service Cost	$ 4,144	$ 4,430	$ 3,697
Interest Cost	10,292	9,357	8,952
Expected Return on Plan Assets	(11,029)	(11,914)	(10,818)
Amortization:
Prior Service Cost (Credits)	203	203	177
Actuarial Loss	7,975	8,969	4,864
Net Periodic Benefit Cost	11,585	11,045	6,872
Capitalized Benefit Costs	(4,645)	(4,805)	(3,047)
Affiliate SERP Allocations	(1,960)	(1,688)	(1,313)
Deferred Benefit Costs	(644)	(1,007)	0
Total Net Periodic Benefit Expense	4,336	3,545	2,512
Other Postretirement Benefits
Net periodic benefit cost [Abstract]
Service Cost	576	726	585
Interest Cost	2,120	2,406	2,297
Expected Return on Plan Assets	(2,823)	(2,708)	(2,467)
Amortization:
Prior Service Cost (Credits)	(257)	499	133
Actuarial Loss	945	1,107	770
Net Periodic Benefit Cost	561	2,030	1,318
Capitalized Benefit Costs	(277)	(1,043)	(722)
Affiliate SERP Allocations	0	0	0
Deferred Benefit Costs	0	(256)	0
Total Net Periodic Benefit Expense	$ 284	$ 731	$ 596

PENSION AND OTHER POSTRETIREM52

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 (Gains)/Losses	9,706	(463)
Amounts Arising During the Period, Prior Service (Cost) Credit	0	0
Amounts Amortized to Net Periodic Costs, Net Actuarial Loss	(5,485)	(6,079)
Amounts Amortized to Net Periodic Costs, Prior Service (Cost) Credit	(203)	(203)
Ending Balance	68,450	64,432
Accumulated Other Comprehensive Loss (pre-tax)
Beginning Balance	20,463	23,170
Amounts Arising During the Period, Net Actuarial (Gains)/Losses	6,129	184
Amounts Arising During the Period, Prior Service Cost (Credit)	0	0
Amounts Amortized to Net Periodic Costs, Net Actuarial Loss	(2,490)	(2,891)
Amounts Amortized to Net Periodic Costs, Prior Service (Cost) Credit	0	0
Ending Balance	24,102	20,463
Other Postretirement Benefits
Regulatory Assets
Beginning Balance	15,347	27,863
Amounts Arising During the Period, Net Actuarial (Gains)/Losses	2,584	(3,155)
Amounts Arising During the Period, Prior Service (Cost) Credit	257	(499)
Amounts Amortized to Net Periodic Costs, Net Actuarial Loss	(945)	(1,107)
Amounts Amortized to Net Periodic Costs, Prior Service (Cost) Credit	0	(7,755)
Ending Balance	17,243	15,347
Accumulated Other Comprehensive Loss (pre-tax)
Beginning Balance	0	0
Amounts Arising During the Period, Net Actuarial (Gains)/Losses	0	0
Amounts Arising During the Period, Prior Service Cost (Credit)	0	0
Amounts Amortized to Net Periodic Costs, Net Actuarial Loss	0	0
Amounts Amortized to Net Periodic Costs, Prior Service (Cost) Credit	0	0
Ending Balance	$ 0	$ 0

PENSION AND OTHER POSTRETIREM53

PENSION AND OTHER POSTRETIREMENT BENEFITS - ESTIMATED COSTS TO BE AMORTIZED (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Prior Service Cost/(Credit)	$ 127
Net Actuarial Loss	6,202
Net Actuarial Loss	2,378
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Prior Service Cost/(Credit)	(257)
Net Actuarial Loss	1,040
Net Actuarial Loss	$ 0

PENSION AND OTHER POSTRETIREM54

PENSION AND OTHER POSTRETIREMENT BENEFITS - RECONCILIATION OF PLANS' BENEFIT OBLIGATION, FAIR VALUE OF PLAN ASSETS, FUNDED STATUS AND AMOUNTS RECOGNIZED IN BALANCE SHEET (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	$ (2,428)	$ (2,227)
Noncurrent Liabilities	(81,800)	(65,491)
Pension Benefits
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	213,660	221,605
Service Cost	4,144	4,430	$ 3,697
Interest Cost	10,292	9,357	8,952
Actuarial Loss (Gain)	17,463	(13,107)
Retiree Contributions	0	0
Plan Amendments	0	0
Benefits Paid	(9,203)	(8,625)
Benefit Obligation at End of Year	236,356	213,660	221,605
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	149,032	144,568
Actual Return on Plan Assets	12,656	(913)
Employer Contributions	2,244	14,002
Retiree Contributions	0	0
Benefits Paid	(9,203)	(8,625)
Fair Value of Plan Assets at End of Year	154,729	149,032	144,568
Funded Status at End of Year:
Accrued Net Benefit Cost at End of Year	(81,627)	(64,628)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	(2,428)	(2,227)
Noncurrent Liabilities	(79,199)	(62,401)
Net Amount Recognized at End of Year	(81,627)	(64,628)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	538	741
Net Actuarial Loss	67,912	63,691
Net Amount Recognized at End of Year	68,450	64,432	71,177
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
Net Actuarial Loss	24,102	20,463
Projected benefit obligation	183,200	167,600
Accumulated benefit obligation	170,000	154,800
Other Postretirement Benefits
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	46,518	60,670
Service Cost	576	726	585
Interest Cost	2,120	2,406	2,297
Actuarial Loss (Gain)	2,292	(6,257)
Retiree Contributions	70	608
Plan Amendments	0	(7,755)
Benefits Paid	(3,027)	(3,880)
Benefit Obligation at End of Year	48,549	46,518	60,670
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	43,428	40,951
Actual Return on Plan Assets	2,531	(395)
Employer Contributions	2,946	6,144
Retiree Contributions	70	608
Benefits Paid	(3,027)	(3,880)
Fair Value of Plan Assets at End of Year	45,948	43,428	40,951
Funded Status at End of Year:
Accrued Net Benefit Cost at End of Year	(2,601)	(3,090)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	0	0
Noncurrent Liabilities	(2,601)	(3,090)
Net Amount Recognized at End of Year	(2,601)	(3,090)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	(3,032)	(3,289)
Net Actuarial Loss	20,275	18,636
Net Amount Recognized at End of Year	17,243	15,347	27,863
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
Net Actuarial Loss	0	0
Supplemental Employee Retirement Plans
Change in Plan Assets:
Employer Contributions	2,300	2,000	$ 1,500
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
Projected benefit obligation	53,200	46,100
Accumulated benefit obligation	$ 51,200	$ 44,600

PENSION AND OTHER POSTRETIREM55

PENSION AND OTHER POSTRETIREMENT BENEFITS - WEIGHTED AVERAGE ASSUMPTIONS USED (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 POSTRETIREM56

PENSION AND OTHER POSTRETIREMENT BENEFITS - PLAN ASSETS (Details) - Pension Benefits	12 Months Ended
	Dec. 31, 2016USD ($)
Defined Benefit Plan Disclosure [Line Items]
Prohibited investments related to capitalization (less than)	$ 250,000,000
Small-cap portion with capitalization levels (as low as)	$ 50,000,000
Equity Securities, U.S. Securities
Defined Benefit Plan Disclosure [Line Items]
Minimum target allocations	28.00%
Maximum target allocations	48.00%
Equity Securities, International Securities
Defined Benefit Plan Disclosure [Line Items]
Minimum target allocations	13.00%
Maximum target allocations	25.00%
Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Minimum target allocations	32.00%
Maximum target allocations	42.00%
Other Investments
Defined Benefit Plan Disclosure [Line Items]
Minimum target allocations	0.00%
Maximum target allocations	7.00%

PENSION AND OTHER POSTRETIREM57

PENSION AND OTHER POSTRETIREMENT BENEFITS - PLAN ASSETS BY CATEGORY (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2016USD ($)category
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total	$ 149,032	$ 144,568	$ 154,729
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	149,032	144,568
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	154,729	149,032
Pension Benefits | Cash
Defined Benefit Plan Disclosure [Line Items]
Total	28	28	52
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	28
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	52	28
Pension Benefits | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Total	692	692	376
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	692
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	376	692
Pension Benefits | STIF-Type Instrument
Defined Benefit Plan Disclosure [Line Items]
Total	1,096	1,096	1,168
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,096
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	1,168	1,096
Pension Benefits | Common/Collective Trust Funds – U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	41,976	41,976	42,369
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	41,976
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	42,369	41,976
Pension Benefits | U.S. Large-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	11,535	11,535	14,523
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	11,535
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	14,523	11,535
Pension Benefits | U.S. Mid-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	2,748	2,748	2,024
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	2,748
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	2,024	2,748
Pension Benefits | U.S. Small-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	210	210	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	210
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	210
Pension Benefits | Equity Securities, International Securities
Defined Benefit Plan Disclosure [Line Items]
Total	1,367	1,367	2,727
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,367
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	2,727	1,367
Pension Benefits | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	26,800	26,800	27,017
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	26,800
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	27,017	26,800
Pension Benefits | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Total	40,853	40,853	44,873
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	40,853
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	44,873	40,853
Pension Benefits | Common/Collective Trust Fund – Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total	6,866	6,866	7,506
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	6,866
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	7,506	6,866
Pension Benefits | Guaranteed Insurance Contract
Defined Benefit Plan Disclosure [Line Items]
Total	8,031	8,031	7,930
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,031
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	7,930	8,031
Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total	3,353	3,353	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,353
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	3,353
Pension Benefits | Private Equity Fund
Defined Benefit Plan Disclosure [Line Items]
Total	3,477	3,477	4,164
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,477
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	$ 4,164	3,477
Pension Benefits | Private Equity Fund | Minimum
Actual return on plan assets:
Lag period for fund valuations	90 days
Pension Benefits | Private Equity Fund | Maximum
Actual return on plan assets:
Lag period for fund valuations	120 days
Pension Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Total	$ 15,888	15,888	19,326
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	15,888
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	19,326	15,888
Pension Benefits | Level 1 | Cash
Defined Benefit Plan Disclosure [Line Items]
Total	28	28	52
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	28
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	52	28
Pension Benefits | Level 1 | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | STIF-Type Instrument
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Common/Collective Trust Funds – U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | U.S. Large-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	11,535	11,535	$ 14,523
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	11,535
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	14,523	11,535
Number of equity investment sectors (in categories) | category			5
Pension Benefits | Level 1 | U.S. Mid-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	2,748	2,748	$ 2,024
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	2,748
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	2,024	2,748
Pension Benefits | Level 1 | U.S. Small-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	210	210	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	210
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	210
Pension Benefits | Level 1 | Equity Securities, International Securities
Defined Benefit Plan Disclosure [Line Items]
Total	1,367	1,367	2,727
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,367
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	2,727	1,367
Pension Benefits | Level 1 | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Common/Collective Trust Fund – Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Guaranteed Insurance Contract
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Private Equity Fund
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2
Defined Benefit Plan Disclosure [Line Items]
Total	111,417	111,417	115,803
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	111,417
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	115,803	111,417
Pension Benefits | Level 2 | Cash
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Total	692	692	376
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	692
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	376	692
Pension Benefits | Level 2 | STIF-Type Instrument
Defined Benefit Plan Disclosure [Line Items]
Total	1,096	1,096	1,168
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,096
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	1,168	1,096
Pension Benefits | Level 2 | Common/Collective Trust Funds – U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	41,976	41,976	42,369
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	41,976
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	42,369	41,976
Pension Benefits | Level 2 | U.S. Large-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | U.S. Mid-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | U.S. Small-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	0		0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0
Pension Benefits | Level 2 | Equity Securities, International Securities
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	26,800	26,800	27,017
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	26,800
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	27,017	26,800
Pension Benefits | Level 2 | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Total	40,853	40,853	44,873
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	40,853
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	44,873	40,853
Pension Benefits | Level 2 | Common/Collective Trust Fund – Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Guaranteed Insurance Contract
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Private Equity Fund
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3
Defined Benefit Plan Disclosure [Line Items]
Total	21,727	21,089	19,600
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	21,727	21,089
Actual return on plan assets:
Relating to assets still held at the reporting date	1,097	514
Relating to assets sold during the period	212	367
Purchases, Sales and Settlements	(3,436)	(243)
Fair Value of Plan Assets at End of Year	19,600	21,727
Pension Benefits | Level 3 | Cash
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | STIF-Type Instrument
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Common/Collective Trust Funds – U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | U.S. Large-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | U.S. Mid-Cap
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Equity Securities, International Securities
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Common/Collective Trust Funds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Common/Collective Trust Fund – Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total	6,866	5,987	7,506
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	6,866	5,987
Actual return on plan assets:
Relating to assets still held at the reporting date	640	879
Relating to assets sold during the period	0	0
Purchases, Sales and Settlements	0	0
Fair Value of Plan Assets at End of Year	7,506	6,866
Pension Benefits | Level 3 | Guaranteed Insurance Contract
Defined Benefit Plan Disclosure [Line Items]
Total	8,031	8,738	7,930
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,031	8,738
Actual return on plan assets:
Relating to assets still held at the reporting date	541	(26)
Relating to assets sold during the period	12	21
Purchases, Sales and Settlements	(654)	(702)
Fair Value of Plan Assets at End of Year	7,930	8,031
Pension Benefits | Level 3 | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total	3,353	3,469	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,353	3,469
Actual return on plan assets:
Relating to assets still held at the reporting date	(13)	(116)
Relating to assets sold during the period	0	0
Purchases, Sales and Settlements	(3,340)	0
Fair Value of Plan Assets at End of Year	0	3,353
Pension Benefits | Level 3 | Private Equity Fund
Defined Benefit Plan Disclosure [Line Items]
Total	3,477	2,895	4,164
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,477	2,895
Actual return on plan assets:
Relating to assets still held at the reporting date	(71)	(223)
Relating to assets sold during the period	200	346
Purchases, Sales and Settlements	558	459
Fair Value of Plan Assets at End of Year	4,164	3,477
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total	43,428	40,951	45,948
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	43,428	40,951
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	45,948	43,428
Other Postretirement Benefits | Cash
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Equity Securities, U.S. Securities | Minimum
Actual return on plan assets:
Target plan allocations	30.00%
Other Postretirement Benefits | Equity Securities, U.S. Securities | Maximum
Actual return on plan assets:
Target plan allocations	43.00%
Other Postretirement Benefits | Common/Collective Trust Funds – U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	$ 12,154	12,154	13,372
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	12,154
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,372	12,154
Other Postretirement Benefits | Mutual Fund - U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	1,228	1,228
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 1,228
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,228
Other Postretirement Benefits | Equity Securities, International Securities | Minimum
Actual return on plan assets:
Target plan allocations	20.00%
Other Postretirement Benefits | Equity Securities, International Securities | Maximum
Actual return on plan assets:
Target plan allocations	30.00%
Other Postretirement Benefits | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	$ 7,471	7,471	7,796
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	7,471
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	7,796	7,471
Other Postretirement Benefits | Mutual Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	922	922
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 922
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		922
Other Postretirement Benefits | Fixed Income Funds | Minimum
Actual return on plan assets:
Target plan allocations	32.00%
Other Postretirement Benefits | Fixed Income Funds | Maximum
Actual return on plan assets:
Target plan allocations	42.00%
Other Postretirement Benefits | Common/Collective Trust Fund – Bonds
Defined Benefit Plan Disclosure [Line Items]
Total	$ 11,852	11,852	12,167
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	11,852
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	12,167	11,852
Other Postretirement Benefits | Mutual Funds - Bonds
Defined Benefit Plan Disclosure [Line Items]
Total	1,352	1,352
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	$ 1,352
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,352
Other Postretirement Benefits | Other Investments | Minimum
Actual return on plan assets:
Target plan allocations	0.00%
Other Postretirement Benefits | Other Investments | Maximum
Actual return on plan assets:
Target plan allocations	7.00%
Other Postretirement Benefits | Mutual Funds - REITs
Defined Benefit Plan Disclosure [Line Items]
Total	$ 142	142
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	142
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		142
Other Postretirement Benefits | Company Owned Life Insurance
Defined Benefit Plan Disclosure [Line Items]
Total	8,281	8,281	12,613
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,281
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	12,613	8,281
Other Postretirement Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Total	3,670	3,670	0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	3,670
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	0	3,670
Other Postretirement Benefits | Level 1 | Cash
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Common/Collective Trust Funds – U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Mutual Fund - U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	1,228	1,228
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,228
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,228
Other Postretirement Benefits | Level 1 | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Mutual Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	922	922
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	922
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		922
Other Postretirement Benefits | Level 1 | Common/Collective Trust Fund – Bonds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 1 | Mutual Funds - Bonds
Defined Benefit Plan Disclosure [Line Items]
Total	1,352	1,352
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	1,352
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		1,352
Other Postretirement Benefits | Level 1 | Mutual Funds - REITs
Defined Benefit Plan Disclosure [Line Items]
Total	142	142
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	142
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		142
Other Postretirement Benefits | Level 1 | Company Owned Life Insurance
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2
Defined Benefit Plan Disclosure [Line Items]
Total	39,758	39,758	45,948
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	39,758
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	45,948	39,758
Other Postretirement Benefits | Level 2 | Cash
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Common/Collective Trust Funds – U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	12,154	12,154	13,372
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	12,154
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	13,372	12,154
Other Postretirement Benefits | Level 2 | Mutual Fund - U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	7,471	7,471	7,796
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	7,471
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	7,796	7,471
Other Postretirement Benefits | Level 2 | Mutual Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Common/Collective Trust Fund – Bonds
Defined Benefit Plan Disclosure [Line Items]
Total	11,852	11,852	12,167
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	11,852
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	12,167	11,852
Other Postretirement Benefits | Level 2 | Mutual Funds - Bonds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Mutual Funds - REITs
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 2 | Company Owned Life Insurance
Defined Benefit Plan Disclosure [Line Items]
Total	8,281	8,281	12,613
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	8,281
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	12,613	8,281
Other Postretirement Benefits | Level 3
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Cash
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Common/Collective Trust Funds – U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Mutual Fund - U.S.
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Common/Collective Trust Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Mutual Funds - International
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Common/Collective Trust Fund – Bonds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Mutual Funds - Bonds
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Mutual Funds - REITs
Defined Benefit Plan Disclosure [Line Items]
Total	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 | Level 3 | Company Owned Life Insurance
Defined Benefit Plan Disclosure [Line Items]
Total	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 POSTRETIREM58

PENSION AND OTHER POSTRETIREMENT BENEFITS - FUTURE BENEFIT PAYMENTS (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]
Contributions to qualified employee pension plans	$ 0	$ 12,020,000	$ 0
Pension Benefits
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
2,017	10,339,000
2,018	10,619,000
2,019	11,472,000
2,020	11,921,000
2,021	12,481,000
2022- 2026	73,847,000
Contributions to qualified employee pension plans	12,000,000	0
Employer Contributions	2,244,000	14,002,000
Other Postretirement Benefits
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
2,017	3,600,000
2,018	3,577,000
2,019	3,677,000
2,020	3,790,000
2,021	3,811,000
2022- 2026	18,131,000
Employer Contributions	2,946,000	6,144,000
Estimated future contributions	3,600,000
Supplemental Employee Retirement Plans
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
Employer Contributions	2,300,000	$ 2,000,000	$ 1,500,000
Estimated future contributions	$ 2,400,000

PENSION AND OTHER POSTRETIREM59

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 the matching provision | $	$ 1.3	$ 1.2	$ 1.2
Employee Qualifying For Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Match of participants' contributions	50.00%
Match of participants contributions of base compensation (up to)	6.00%
Employee Not Qualifying For Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Match of participants' contributions	50.00%
Match of participants contributions of base compensation (up to)	8.00%
Additional year-end compensation	1,500
Threshold of service	10 years
Additional year-end compensation	2,000

COMMITMENTS AND CONTINGENCIES60

COMMITMENTS AND CONTINGENCIES (Details)	12 Months Ended		444 Months Ended
	Dec. 31, 2016USD ($)siteunion	Dec. 31, 2015USD ($)	Dec. 31, 2016USD ($)siteunion	Dec. 31, 2012USD ($)site
Loss Contingencies [Line Items]
Letter of credit provided	$ 210,000,000		$ 210,000,000
Gas supply related demand charges and reservation fees	5,600,000
Amount accrued related to all claims	$ 600,000	$ 800,000	$ 600,000
Percentage of workforce represented by unions	62.00%		62.00%
Number of unions | union	2		2
Number of sites for environmental cleanup | site	12		12
Number of sites covered by insurance | site				11
Insurance policy limit				$ 50,000,000
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning of Year	$ 123,194,000	124,308,000
Accruals	61,933,000	18,747,000	$ 420,200,000
Expenditures	(32,080,000)	(19,861,000)	(267,200,000)
End of Year	153,047,000	$ 123,194,000	153,047,000
Pending litigation | Pricing dispute related to a long-term gas supply contract
Loss Contingencies [Line Items]
Counter-suit amount sought	14,900,000
Standby Letter of Credit
Loss Contingencies [Line Items]
Letter of credit provided	$ 25,200,000		$ 25,200,000
Environmental Restoration Costs | Sites comprising the majority of the environmental remediation
Accrual for Environmental Loss Contingencies [Roll Forward]
Number of sites affected by environmental remediation | site	6		6
Environmental Restoration Costs | Minimum
Accrual for Environmental Loss Contingencies [Roll Forward]
Estimated future costs to clean up sites	$ 153,000,000		$ 153,000,000
Environmental Restoration Costs | Minimum | Sites comprising the majority of the environmental remediation
Accrual for Environmental Loss Contingencies [Roll Forward]
Estimated future costs to clean up sites	141,200,000		141,200,000
Environmental Restoration Costs | Maximum
Accrual for Environmental Loss Contingencies [Roll Forward]
Estimated future costs to clean up sites	257,100,000		257,100,000
Environmental Restoration Costs | Maximum | Sites comprising the majority of the environmental remediation
Accrual for Environmental Loss Contingencies [Roll Forward]
Estimated future costs to clean up sites	$ 246,700,000		$ 246,700,000

FAIR VALUE OF FINANCIAL ASSET61

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Assets
Available-for-Sale Securities		$ 8,788
Derivatives - Energy Related Assets	$ 5,807	1,141
Total Assets	5,807	9,929
Liabilities
Derivatives - Energy Related Liabilities	1,372	5,840
Derivatives - Other	7,365	7,631
Total Liabilities	8,737	13,471
Level 1
Assets
Available-for-Sale Securities		1,722
Derivatives - Energy Related Assets	4,767	398
Total Assets	4,767	2,120
Liabilities
Derivatives - Energy Related Liabilities	6	5,424
Derivatives - Other	0	0
Total Liabilities	6	5,424
Level 2
Assets
Available-for-Sale Securities		7,066
Derivatives - Energy Related Assets	0	144
Total Assets	0	7,210
Liabilities
Derivatives - Energy Related Liabilities	1,252	0
Derivatives - Other	7,365	7,631
Total Liabilities	8,617	7,631
Level 3
Assets
Available-for-Sale Securities		0
Derivatives - Energy Related Assets	1,040	599
Total Assets	1,040	599
Liabilities
Derivatives - Energy Related Liabilities	114	416
Derivatives - Other	0	0
Total Liabilities	$ 114	$ 416

FAIR VALUE OF FINANCIAL ASSET62

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES - QUANTITATIVE INFORMATION ON LEVEL 3 MEASUREMENTS (Details) - Level 3 - Forward Contract - Natural Gas $ in Thousands	Dec. 31, 2016USD ($)$ / decatherm	Dec. 31, 2015USD ($)$ / decatherm
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	$ 1,040	$ 599
Liabilities | $	$ 114	$ 416
Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Forward price (in dollars per dt)	3.25	1.18
Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Forward price (in dollars per dt)	6.33	5.21
Weighted Average
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Forward price (in dollars per dt)	5.09	2.90

FAIR VALUE OF FINANCIAL ASSET63

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES - FAIR VALUE MEASUREMENTS OF DERIVATES (Details) - Level 3 - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance (beginning)	$ 183	$ 0
Other Changes in Fair Value from Continuing and New Contracts, Net	926	183
Settlements	(183)	0
Balance (ending)	$ 926	$ 183

DERIVATIVE INSTRUMENTS (Details

DERIVATIVE INSTRUMENTS (Details)	1 Months Ended	12 Months Ended
	Sep. 30, 2005USD ($)	Dec. 31, 2016USD ($)MMcfe	Dec. 31, 2015USD ($)
Derivative [Line Items]
Unrealized gain (losses) included in its BGSS related to open financial contracts		$ 4,400,000	$ (4,700,000)
Initial cost of Treasury Locks	$ 1,400,000
Amortization period of Treasury Locks	30 years
Unamortized balance of Treasury Locks		900,000	$ 900,000
Interest Rate Swap, $12,500,000 Contract 1
Derivative [Line Items]
Notional Amount		$ 12,500,000,000
Fixed Interest Rate		3.53%
Interest Rate Swap, $12,500,000 Contract 2
Derivative [Line Items]
Notional Amount		$ 12,500,000,000
Fixed Interest Rate		3.43%
Basis and Index Related Purchase and Sales Contracts
Derivative [Line Items]
Notional amount (mmcfe) | MMcfe		1,300
Derivative Transaction Type, Purchase
Derivative [Line Items]
Notional amount (mmcfe) | MMcfe		8,500
Derivative Transaction Type, Sale
Derivative [Line Items]
Notional amount (mmcfe) | MMcfe		600

DERIVATIVE INSTRUMENTS - FAIR V

DERIVATIVE INSTRUMENTS - FAIR VALUE OF ALL DERIVATIVE INSTRUMENTS (Details) - Not Designated as Hedging Instrument - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Assets	$ 5,807	$ 1,141
Liabilities	8,737	13,471
Energy related commodity contracts | Derivatives – Energy Related – Current
Derivatives, Fair Value [Line Items]
Assets	5,434	1,077
Liabilities	1,372	5,489
Energy related commodity contracts | Derivatives – Energy Related – Non-Current
Derivatives, Fair Value [Line Items]
Assets	373	64
Liabilities	0	351
Interest rate contract | Derivatives – Other Current
Derivatives, Fair Value [Line Items]
Liabilities	386	0
Interest rate contract | Derivatives – Other Noncurrent
Derivatives, Fair Value [Line Items]
Assets	0	0
Liabilities	$ 6,979	$ 7,631

DERIVATIVE INSTRUMENTS - OFFSET

DERIVATIVE INSTRUMENTS - OFFSETTING ARRANGEMENTS (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Derivatives - Energy Related
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets	$ 5,807	$ 1,141
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	5,807	1,141
Gross amounts not offset in the balance sheet, Financial Instruments	(6)	(399)
Gross amounts not offset in the balance sheet, Cash Collateral Posted	(3,587)	0
Net amount	2,214	742
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized liabilities	(1,372)	(5,840)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(1,372)	(5,840)
Gross amounts not offset in the balance sheet, Financial Instruments	6	399
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0	5,025
Net amount	(1,366)	(416)
Derivatives - Other
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized liabilities	(7,365)	(7,631)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(7,365)	(7,631)
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	$ (7,365)	$ (7,631)

DERIVATIVE INSTRUMENTS - DERIVA

DERIVATIVE INSTRUMENTS - DERIVATIVES IN CASH FLOW HEDGING RELATIONSHIPS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Losses reclassified from accumulated OCI into income	$ (46)	$ (46)	$ (46)
Net realized (losses) gains associated with energy-related financial commodity contracts	$ (3,000)	$ (9,100)	$ 1,700

ACCUMULATED OTHER COMPREHENSI68

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 (beginning)		$ 707,927
Other comprehensive income before reclassifications		(3,364)	$ (186)
Losses from reclassifications for the period net of tax		1,292	1,803
Net current period other comprehensive income	[1],[2]	(2,072)	1,617	$ (3,610)
Balance (ending)		$ 839,900	$ 707,927
Combined statutory tax rate		40.00%	40.00%	40.00%
Total
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance (beginning)		$ (12,862)	$ (14,479)
Net current period other comprehensive income	[2],[3]	(2,072)	1,617	$ (3,610)
Balance (ending)		(14,934)	(12,862)	(14,479)
Postretirement Liability Adjustment
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance (beginning)		(12,220)	(13,837)
Other comprehensive income before reclassifications		(3,687)	(110)
Losses from reclassifications for the period net of tax		1,490	1,727
Net current period other comprehensive income	[3]	(2,197)	1,617	(3,165)
Balance (ending)		(14,417)	(12,220)	(13,837)
Unrealized Gain (Loss) on Derivatives-Other
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance (beginning)		(544)	(567)
Other comprehensive income before reclassifications		0	0
Losses from reclassifications for the period net of tax		27	23
Net current period other comprehensive income	[3]	27	23	27
Balance (ending)		(517)	(544)	(567)
Unrealized Gain (Loss) on Available-for-Sale Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance (beginning)		(98)	(75)
Other comprehensive income before reclassifications		323	(76)
Losses from reclassifications for the period net of tax		(225)	53
Net current period other comprehensive income	[3]	98	(23)	(472)
Balance (ending)		$ 0	$ (98)	$ (75)
[1]	Determined using a combined statutory tax rate of 40% in each of 2016, 2015 and 2014.
[2]	Determined using a combined statutory tax rate of 40%.
[3]	Determined using a combined statutory tax rate of 40%.

ACCUMULATED OTHER COMPREHENSI69

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) - Additional Details (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]
Operating Expenses: Operations									$ 95,609	$ 107,836	$ 102,428
Total Income Tax Expense	$ 12,554	$ (2,007)	$ 1,415	$ 27,404	$ 10,352	$ (2,871)	$ 3,292	$ 26,172	39,366	36,945	$ 34,895
Losses from reclassifications for the period net of tax									$ 1,292	$ 1,803
Combined statutory rate									40.00%	40.00%	40.00%
Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Losses from reclassifications for the period net of tax									$ 27	$ 23
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									(225)	53
Actuarial Loss on Postretirement Benefits
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Losses from reclassifications for the period net of tax									1,490	1,727
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]
Total Income Tax Expense									(19)	(23)
Net income (loss)									27	23
Amounts Reclassified from AOCL | Unrealized Gain (Loss) on Available-for-Sale Securities
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Other Income & Expense									(377)	90
Total Income Tax Expense									152	(37)
Net income (loss)									(225)	53
Amounts Reclassified from AOCL | Actuarial Loss on Postretirement Benefits
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Operating Expenses: Operations									2,490	2,891
Total Income Tax Expense									(1,000)	(1,164)
Net income (loss)									1,490	1,727
Interest rate contract | 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]
Interest Charges									$ 46	$ 46

QUARTERLY RESULTS OF OPERATIO70

QUARTERLY RESULTS OF OPERATIONS - UNAUDITED (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
Quarterly Financial Information Disclosure [Abstract]
Operating Revenues	$ 142,502	$ 62,025	$ 68,762	$ 187,766	$ 132,186	$ 58,634	$ 75,812	$ 267,658	$ 461,055	$ 534,290	$ 501,875
Expenses:
Cost of Sales (excluding depreciation)	58,695	26,395	19,997	69,303	50,835	22,934	25,419	146,102	174,390	245,290	231,216
Operations and Maintenance Including Fixed Charges	47,886	41,303	42,826	46,450	48,258	42,204	42,691	52,137
Income Taxes	12,554	(2,007)	1,415	27,404	10,352	(2,871)	3,292	26,172	39,366	36,945	34,895
Energy and Other Taxes	1,195	838	560	1,027	951	806	854	1,420	3,620	4,031	3,760
Total Expenses	120,330	66,529	64,798	144,184	110,396	63,073	72,256	225,831
Other Income and Expense	727	1,189	1,079	836	404	1,010	1,670	760
Net Income	$ 22,899	$ (3,315)	$ 5,043	$ 44,418	$ 22,194	$ (3,429)	$ 5,226	$ 42,587	$ 69,045	$ 66,578	$ 66,483

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details)	1 Months Ended
	Jan. 31, 2017USD ($)bank	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Subsequent Event [Line Items]
Term loan credit agreement		$ 210,000,000
Loans Payable | Term Line of Credit
Subsequent Event [Line Items]
Term loan credit agreement		200,000,000
Outstanding debt		$ 200,000,000	$ 139,000,000
Subsequent event | Credit Agreement | Unsecured term loan
Subsequent Event [Line Items]
Credit agreement syndicated among number of banks | bank	7
Subsequent event | South Jersey Gas Company | Unsecured term loan
Subsequent Event [Line Items]
Outstanding debt	$ 73,000,000
Subsequent event | South Jersey Gas Company | Credit Agreement | Unsecured term loan
Subsequent Event [Line Items]
Term loan credit agreement	200,000,000
Subsequent event | South Jersey Gas Company | Medium-term Notes | Series E, 2017, due January 2047
Subsequent Event [Line Items]
Aggregate principal amount issued	$ 200,000,000
Stated interest rate	3.00%
Subsequent event | South Jersey Gas Company | Loans Payable | Term Line of Credit
Subsequent Event [Line Items]
Pay down of multiple-draw term facility	$ 200,000,000

SCHEDULE II - VALUATION AND Q72

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS (Details) - Allowance for Doubtful 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	$ 9,778	$ 6,601	$ 4,553
Charged to Costs and Expenses	6,993	14,689	9,417
Charged to Other Accounts	(47)	(235)	(102)
Deductions	4,154	11,277	7,267
Balance	$ 12,570	$ 9,778	$ 6,601