South Jersey Industries (SJIIU) 10-K 29 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2015	Feb. 15, 2016	Jun. 30, 2015
Entity [Abstract]
Entity Registrant Name	SOUTH JERSEY INDUSTRIES INC
Entity Central Index Key	91,928
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		71,130,732
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 1,687,786,543

Statements of Consolidated Inco

Statements of Consolidated Income shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares	Dec. 31, 2013USD ($)$ / sharesshares
Operating Revenues:
Utility	$ 528,763	$ 500,752	$ 444,920
Nonutility	430,805	386,244	286,501
Total Operating Revenues	959,568	886,996	731,421
Cost of Sales - (Excluding depreciation)
- Utility	239,763	230,093	198,521
- Nonutility	319,579	306,859	270,470
Operations	148,672	140,260	120,205
Maintenance	16,183	13,457	13,136
Depreciation	72,451	63,004	49,637
Energy and Other Taxes	6,026	5,720	9,816
Total Operating Expenses	802,674	759,393	661,785
Operating Income	156,894	127,603	69,636
Other Income and Expense	9,510	11,819	10,979
Interest Charges	(31,622)	(29,560)	(18,825)
Income Before Income Taxes	134,782	109,862	61,790
Income Taxes	(1,360)	(4,449)	19,014
Equity in (Loss) Earnings of Affiliated Companies	(27,812)	(7,785)	1,585
Income from Continuing Operations	105,610	97,628	82,389
Loss from Discontinued Operations - (Net of tax benefit)	(503)	(582)	(796)
Net Income	$ 105,107	$ 97,046	$ 81,593
Basic Earnings per Common Share:
Continuing Operations (in USD per share) | $ / shares	$ 1.54	$ 1.47	$ 1.29
Discontinued Operations (in USD per share) | $ / shares	(0.01)	(0.01)	(0.01)
Basic Earnings per Common Share (in USD per share) | $ / shares	$ 1.53	$ 1.46	$ 1.28
Average Shares of Common Stock Outstanding - Basic (in shares) | shares	68,735	66,278	63,978
Diluted Earnings per Common Share:
Continuing Operations (in USD per share) | $ / shares	$ 1.53	$ 1.47	$ 1.29
Discontinued Operations (in USD per share) | $ / shares	(0.01)	(0.01)	(0.01)
Diluted Earnings per Common Share (in USD per share) | $ / shares	$ 1.52	$ 1.46	$ 1.28
Average Shares of Common Stock Outstanding - Diluted (in shares) | shares	68,931	66,428	64,092

Statements of Consolidated Comp

Statements of Consolidated Comprehensive Income - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Comprehensive Income [Abstract]
Net Income		$ 105,107	$ 97,046	$ 81,593
Other Comprehensive (Loss) Income, Net of Tax:
Postretirement Liability Adjustment	[1]	5,518	(9,160)	4,934
Unrealized (Loss) Gain on Available-for-Sale Securities	[1]	(53)	(472)	103
Unrealized Gain on Derivatives - Other	[1]	321	247	265
Other Comprehensive (Loss) Income of Affiliated Companies	[1]	(27)	(113)	5,043
Other Comprehensive (Loss) Income - Net of Tax	[1]	5,759	(9,498)	10,345
Comprehensive Income		$ 110,866	$ 87,548	$ 91,938
Additional Statement Information [Abstract]
Combined statutory tax rate		40.00%	40.00%	41.00%
[1]	For 2015 and 2014, determined using a combined average statutory tax rate of 40%. For 2013, determined using a combined statutory tax rate of 41%.

Statements of Consolidated Cash

Statements of Consolidated Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash Flows from Operating Activities:
Net Income	$ 105,107	$ 97,046	$ 81,593
Loss from Discontinued Operations	503	582	796
Income from Continuing Operations	105,610	97,628	82,389
Adjustments to Reconcile Income from Continuing Operations to Net Cash Provided by Operating Activities:
Depreciation and Amortization	91,042	78,511	64,890
Net Unrealized (Gain) Loss on Derivatives - Energy Related	(8,401)	6,592	25,823
Unrealized (Gain) Loss on Derivatives - Other	(96)	467	(2,760)
Provision for Losses on Accounts Receivable	14,730	9,519	4,245
CIP Receivable/Payable	(7,324)	15,226	21,160
Deferred Gas Costs - Net of Recoveries	28,648	(44,976)	5,473
Deferred SBC Costs - Net of Recoveries	9,557	11,048	2,393
Stock-Based Compensation Expense	2,213	1,893	3,001
Deferred and Noncurrent Income Taxes - Net	3,861	1,670	(21,549)
Environmental Remediation Costs - Net	(22,057)	(8,265)	(367)
Gas Plant Cost of Removal	(5,096)	(4,848)	(6,092)
Pension Contribution	(15,000)	0	(12,700)
Changes in:
Accounts Receivable	92,624	(14,323)	(67,825)
Inventories	9,226	(4,787)	(2,449)
Prepaid and Accrued Taxes - Net	(9,091)	(5,822)	17,703
Accounts Payable and Other Accrued Liabilities	(103,410)	27,429	49,444
Derivatives - Energy Related	(8,069)	169	1,500
Other Assets and Liabilities	8,860	(5,444)	(3,769)
Cash Flows from Discontinued Operations	(1,033)	(355)	(975)
Net Cash Provided by Operating Activities	186,794	161,332	159,535
Cash Flows from Investing Activities:
Capital Expenditures	(345,621)	(342,578)	(316,644)
Purchase of Available for Sale Securities	(6,059)	0	0
Proceeds from Sale of Property, Plant and Equipment	0	53	0
Net Proceeds from Sale of (Purchase of) Restricted Investments in Margin Accounts	20,069	(22,337)	(25,164)
Net Sale of Restricted Investments from Escrowed Loan Proceeds	101	0	0
Investment in Long-Term Receivables	(19,033)	(13,024)	(7,182)
Proceeds from Long-Term Receivables	8,769	6,544	5,764
Notes Receivable	(9,916)	0	0
Purchase of Company-Owned Life Insurance	(2,328)	(1,250)	(5,149)
Acquisition of Subsidiary, Net of Cash Acquired	1,394	0	0
Investment in Affiliate	(20,229)	0	(2,973)
Advances on Notes Receivable - Affiliate	(2,075)	(7,521)	(19,349)
Repayment of Notes Receivable - Affiliate	4,276	5,094	124,946
Other	0	0	(41)
Net Cash Used in Investing Activities	(370,652)	(375,019)	(245,792)
Cash Flows from Financing Activities:
Net Borrowings from (Repayments of) Short-Term Credit Facilities	186,000	(108,200)	65,000
Proceeds from Issuance of Long-Term Debt	130,000	329,000	50,000
Payments for Issuance of Long-Term Debt	(64)	(2,184)	(411)
Principal Repayments of Long-Term Debt	(125,009)	(21,000)	(25,000)
Dividends on Common Stock	(70,158)	(63,869)	(57,679)
Proceeds from Sale of Common Stock	63,192	80,680	54,028
Other	(397)	(387)	(501)
Net Cash Provided by Financing Activities	183,564	214,040	85,437
Net (Decrease) Increase in Cash and Cash Equivalents	(294)	353	(820)
Cash and Cash Equivalents at Beginning of Year	4,171	3,818	4,638
Cash and Cash Equivalents at End of Year	3,877	4,171	3,818
Cash paid during the year for:
Interest (Net of Amounts Capitalized)	30,915	28,854	18,584
Income Taxes (Net of Refunds)	1,828	6,858	(12,387)
Supplemental Disclosures of Non-Cash Investing Activities
Capital Expenditures acquired on account but unpaid as of year-end	51,433	36,491	44,874
Notes Receivable from Affiliate Exchanged for Notes Receivable from a Third Party	$ 16,389	$ 0	$ 7,882

Consolidated Balance Sheets

Consolidated Balance Sheets $ in Thousands		12 Months Ended
		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Property, Plant and Equipment:
Utility Plant, at original cost		$ 2,211,239	$ 2,002,966
Accumulated Depreciation		(440,473)	(413,597)
Nonutility Property and Equipment, at cost		785,646	622,079
Accumulated Depreciation		(108,307)	(77,345)
Property, Plant and Equipment - Net		2,448,105	2,134,103
Investments:
Available-for-Sale Securities		14,810	8,922
Restricted Investments		48,758	65,451
Investment in Affiliates		16,983	68,351
Total Investments		80,551	142,724
Current Assets:
Cash and Cash Equivalents		3,877	4,171
Accounts Receivable		178,359	251,892
Unbilled Revenues		40,044	62,608
Provision for Uncollectibles		(10,252)	(7,910)
Notes Receivable		11,800	0
Notes Receivable - Affiliate		3,134	14,657
Natural Gas in Storage, average cost		54,211	63,246
Materials and Supplies, average cost		5,088	2,125
Deferred Income Taxes - Net		0	57,748
Prepaid Taxes		21,753	14,106
Derivatives - Energy Related Assets		83,093	85,368
Other Prepayments and Current Assets		40,167	18,686
Total Current Assets		431,274	566,697
Regulatory and Other Noncurrent Assets:
Regulatory Assets		323,434	357,160
Derivatives - Energy Related Assets		16,238	13,905
Unamortized Debt Issuance Costs		8,967	9,795
Notes Receivable - Affiliate		13,275	36,799
Contract Receivables		28,609	19,236
Notes Receivable		35,439	7,882
Goodwill		8,880	0
Identifiable Intangible Assets		21,553	0
Other		64,575	61,124
Total Regulatory and Other Noncurrent Assets		520,970	505,901
Total Assets		3,480,900	3,349,425
Common Stock: Par Value $1.25 per share; Authorized 120,000,000 shares; Outstanding Shares: 70,965,622 (2015) and 68,334,860 (2014)
Balance at Beginning of Year		85,418	81,788
Common Stock Issued or Granted Under Stock Plans		3,289	3,630
Balance at End of Year		88,707	85,418
Premium on Common Stock		499,460	438,384
Treasury Stock (at par)		(296)	(330)
Accumulated Other Comprehensive Loss	[1]	(24,499)	(30,258)
Retained Earnings		474,167	439,218
Total Equity		1,037,539	932,432
Long-Term Debt	[2]	1,006,394	859,491
Total Capitalization		2,043,933	1,791,923
Current Liabilities:
Notes Payable		431,700	245,700
Current Portion of Long-Term Debt	[2]	29,454	149,909
Accounts Payable		186,400	272,998
Customer Deposits and Credit Balances		20,146	17,958
Environmental Remediation Costs		50,559	30,430
Taxes Accrued		2,336	2,328
Derivatives - Energy Related Liabilities		90,708	109,744
Interest Accrued		7,316	7,088
Pension Benefits		2,261	1,550
Other Current Liabilities		11,596	12,480
Total Current Liabilities		832,476	850,185
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net		295,945	344,520
Investment Tax Credits		0	149
Pension and Other Postretirement Benefits		76,068	115,373
Environmental Remediation Costs		76,064	97,742
Asset Retirement Obligations		57,943	42,502
Derivatives - Energy Related Liabilities		21,697	19,926
Derivatives - Other		10,943	10,732
Regulatory Liabilities		42,841	41,899
Finance Obligation		0	19,659
Other		22,990	14,815
Total Deferred Credits and Other Noncurrent Liabilities		$ 604,491	$ 707,317
Commitments and Contingencies (Note 15)
Total Capitalization and Liabilities		$ 3,480,900	$ 3,349,425
[1]	Determined using a combined average statutory tax rate of 40%.
[2]	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2016, $29,454; 2017, $172,558; 2018,$40,667; 2019,$260,783; and 2020, $74,476.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2015	Feb. 26, 2015	Feb. 25, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]
Common stock, par value (in USD per share)	$ 1.25			$ 1.25
Common Stock, authorized (in shares)	120,000,000	120,000,000	60,000,000	120,000,000
Common stock, outstanding	70,965,622			68,334,860	65,430,084	63,306,524

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity and Comprehensive Income - USD ($) $ in Thousands		Total	Common Stock [Member]	Premium on Common Stock [Member]	Treasury Stock [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]
Balance at Dec. 31, 2012		$ 736,214	$ 79,134	$ 306,422	$ (364)	$ (31,105)	$ 382,127
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income		81,593					81,593
Other Comprehensive (Loss) Income, Net of Tax	[1]	10,345				10,345
Common Stock Issued or Granted Under Stock Plans		56,527	2,654	53,881	(8)
Cash Dividends Declared - Common Stock ($1.02 per share, $0.96 per share, and $0.90 per share for 2015, 2014, and 2013, respectively)		(57,679)					(57,679)
Balance at Dec. 31, 2013		$ 827,000	81,788	360,303	(372)	(20,760)	406,041
Additional Statement Information [Abstract]
Combined statutory tax rate		41.00%
Net Income		$ 97,046					97,046
Other Comprehensive (Loss) Income, Net of Tax	[1]	(9,498)				(9,498)
Common Stock Issued or Granted Under Stock Plans		81,753	3,630	78,081	42
Cash Dividends Declared - Common Stock ($1.02 per share, $0.96 per share, and $0.90 per share for 2015, 2014, and 2013, respectively)		(63,869)					(63,869)
Balance at Dec. 31, 2014		$ 932,432	85,418	438,384	(330)	(30,258)	439,218
Additional Statement Information [Abstract]
Combined statutory tax rate		40.00%
Net Income		$ 105,107					105,107
Other Comprehensive (Loss) Income, Net of Tax	[1]	5,759				5,759
Common Stock Issued or Granted Under Stock Plans		64,399	3,289	61,076	34
Cash Dividends Declared - Common Stock ($1.02 per share, $0.96 per share, and $0.90 per share for 2015, 2014, and 2013, respectively)		(70,158)					(70,158)
Balance at Dec. 31, 2015		$ 1,037,539	$ 88,707	$ 499,460	$ (296)	$ (24,499)	$ 474,167
Additional Statement Information [Abstract]
Combined statutory tax rate		40.00%
[1]	For 2015 and 2014, determined using a combined average statutory tax rate of 40%. For 2013, determined using a combined statutory tax rate of 41%.

Consolidated Statements of Cha8

Consolidated Statements of Changes in Equity and Comprehensive Income (Parenthetical) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Statement of Stockholders' Equity [Abstract]
Dividends Declared per Common Share (in USD per share)		$ 1.02		$ 0.96		$ 0.9
Combined statutory tax rate		40.00%		40.00%		41.00%
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]
Balance at January 1	[1]	$ (30,258)
Changes During Year	[2]	5,759		$ (9,498)		$ 10,345
Balance at December 31	[1]	(24,499)		(30,258)
Postretirement Liability Adjustment [Member]
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]
Balance at January 1	[2]	(27,663)	[1]	(18,503)		(23,437)
Changes During Year	[2]	5,518		(9,160)		4,934
Balance at December 31	[2]	(22,145)	[1]	(27,663)	[1]	(18,503)
Unrealized Gain (Loss) on Derivatives-Other [Member]
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]
Balance at January 1	[2]	(2,450)	[1]	(2,697)		(2,962)
Changes During Year	[2]	321		247		265
Balance at December 31	[2]	(2,129)	[1]	(2,450)	[1]	(2,697)
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]
Balance at January 1	[2]	(75)	[1]	397		294
Changes During Year	[2]	(53)		(472)		103
Balance at December 31	[2]	(128)	[1]	(75)	[1]	397
Other Comprehensive Income (Loss) of Affiliated Companies [Member]
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]
Balance at January 1	[2]	(70)		43		(5,000)
Changes During Year	[2]	(27)		(113)		5,043
Balance at December 31	[2]	(97)		(70)		43
Accumulated Other Comprehensive Loss [Member]
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]
Balance at January 1	[2]	(30,258)		(20,760)		(31,105)
Changes During Year	[2]	5,759		(9,498)		10,345
Balance at December 31	[2]	$ (24,499)		$ (30,258)		$ (20,760)
[1]	Determined using a combined average statutory tax rate of 40%.
[2]	For 2015 and 2014, determined using a combined average statutory tax rate of 40%. For 2013, determined using a combined statutory tax rate of 41%.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy-related products and services primarily through the following wholly-owned subsidiaries: ▪ South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey. ▪ South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers. ▪ South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets along with fuel management services on a wholesale basis in the mid-Atlantic, Appalachian and southern states. ▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. ▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. The following entities are wholly-owned subsidiaries of Marina as of December 31, 2015 (see Note 3): • ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey. • AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties located in New Jersey. • MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey. ▪ South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. • SJI Midstream, LLC was formed in 2014 to invest in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey. BASIS OF PRESENTATION - The consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI's financial position, operating results and cash flows at the dates and for the periods presented. Certain reclassifications have been made to the prior period's regulatory liabilities disclosure to conform to the current period presentation. The societal benefit costs payable previously included in "Other Regulatory Liabilities" were reclassified to the line item "Societal Benefit Costs Payable" in the regulatory liabilities table disclosed in Note 11. Certain reclassifications have been made to the prior period's deferred tax asset/liability disclosure to conform to the current period presentation. The breakout of current and noncurrent assets/liabilities previously disclosed in Note 4 was reclassified to separate deferred tax assets and deferred tax liabilities as disclosed in Note 4. On February 26, 2015, the Board of Directors approved an amendment to SJI's Certificate of Incorporation to increase the authorized number of shares of common stock from 60,000,000 shares to 120,000,000 shares. The principal purpose of the increase was to permit a two -for-one split of all the issued shares of SJI's common stock, effected pursuant to a stock dividend of one share of common stock for each outstanding share of common stock, payable May 8, 2015 to shareholders of record at the close of business on April 17, 2015. All references to number of shares and per share information in the consolidated financial statements and related notes have been adjusted for all periods presented to reflect this stock split. EQUITY INVESTMENTS - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. SJI, through wholly owned subsidiaries, holds significant variable interests in several companies but is not the primary beneficiary. Consequently, these investments are accounted for under the equity method. In the event that losses and/or distributions from these equity method investments exceed the carrying value, and the Company is obligated to provide additional financial support, the excess will be recorded as either a current or non-current liability on the consolidated balance sheets. We include the operations of these affiliated companies on a pre-tax basis in the statements of consolidated income under Equity in (Loss) Earnings of Affiliated Companies (See Note 3). An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary. In 2015, the Company r ecorded a $7.7 million (net of tax) no n-cash charge to earnings due to the reduction in the carrying value of an investment in a project entered into by Energenic (See Note 7). No impairment losses were recorded on Investments during 2014 or 2013 . ESTIMATES AND ASSUMPTIONS - We prepare our consolidated financial statements to conform with accounting principles generally accepted in the United States of America (GAAP). Management makes estimates and assumptions that affect the amounts reported in the consolidated financial statements and related disclosures. Therefore, actual results could differ from those estimates. Significant estimates include amounts related to regulatory accounting, energy derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition. REGULATION - SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 10 for a detailed discussion of SJG's rate structure and regulatory actions. SJG maintains its accounts according to the BPU's prescribed Uniform System of Accounts. SJG follows the accounting for regulated enterprises prescribed by Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980 -”Regulated Operations.” In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 11 for a detailed discussion of regulatory assets and liabilities. OPERATING REVENUES - Gas and electric revenues are recognized in the period the commodity is delivered to customers. For SJG and SJE retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas and electricity delivered from the date of the last meter reading to the end of the month. SJRG's gas revenues are recognized in the period the commodity is delivered. Realized and unrealized gains and losses on energy-related derivative instruments are also recognized in operating revenues for SJRG. See further discussion under Derivative Instruments. SJRG presents revenues and expenses related to its energy trading activities on a net basis in operating revenues. This net presentation has no effect on operating income or net income. We recognize revenues related to SJESP appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenue related to services provided on a time and materials basis is recognized on a monthly basis as the services are provided. Marina recognizes revenue on a monthly basis as services are provided, as lease income is earned, and for on-site energy production that is delivered to its customers. REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. The PUA is included in both utility revenue and cost of sales and totaled $1.2 million , $1.1 million , and $1.2 million in 2015 , 2014 and 2013 , respectively. In prior years, SJG had collected a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). The TEFA was included in both revenues and cost of sales and totaled $4.0 million in 2013. The TEFA was eliminated effective January 1, 2014. 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. PROPERTY, PLANT AND EQUIPMENT - For regulatory purposes, utility plant is stated at original cost, which may be different than SJG's cost if the assets were acquired from another regulated entity. Nonutility plant is stated at cost. The cost of adding, replacing and renewing property is charged to the appropriate plant account. ASSET RETIREMENT OBLIGATIONS - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations the Company has to cut and cap gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO. ARO activity was as follows (in thousands): 2015 2014 AROs as of January 1, $ 42,502 $ 41,687 Accretion 1,675 1,612 Additions 802 664 Settlements (1,110 ) (1,461 ) Revisions in Estimated Cash Flows (A) 14,074 — ARO's as of December 31, $ 57,943 $ 42,502 (A) The revision in estimated cash flows reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings. 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 2015 , 2.2% in 2014 , and 2.3% in 2013 . The actual composite rate may differ from the approved rate as the asset mix changes over time. Except for retirements outside of the normal course of business, accumulated depreciation is charged with the cost of depreciable utility property retired, less salvage. Nonutility property depreciation is computed on a straight-line basis over the estimated useful lives of the property, ranging up to 50 years. Gain or loss on the disposition of nonutility property is recognized in operating income. Effective October 1, 2014, SJG's composite depreciation rate was reduced from 2.4% to 2.1% . See Note 10. CAPITALIZED INTEREST - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in SJG's last base rate proceeding. For SJG's accelerated infrastructure programs, SJG capitalizes interest on construction at a rate prescribed by the programs (see Note 10). Marina, SJRG and SJE capitalize interest on capital projects in progress based on the actual cost of borrowed funds. SJG's amounts are included in Utility Plant and Marina's amounts are included in Nonutility Property and Equipment on the consolidated balance sheets. Interest Charges are presented net of capitalized interest on the statements of consolidated income. The amount of interest capitalized by SJI for the years ended December 31, 2015 , 2014 and 2013 was $4.9 million , $4.6 million and $8.7 million , respectively. IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the years ended December 31, 2015, 2014 and 2013, no significant impairments were identified. DERIVATIVE INSTRUMENTS - SJI accounts for derivative instruments in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.” We record all derivatives, whether designated in hedging relationships or not, on the consolidated balance sheets at fair value unless the derivative contracts qualify for the normal purchase and sale exemption. In general, if the derivative is designated as a fair value hedge, we recognize the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk in earnings. We currently have no fair value hedges. If the derivative is designated as a cash flow hedge, we record the effective portion of the hedge in Accumulated Other Comprehensive Loss and recognize it in the income statement when the hedged item affects earnings. We recognize ineffective portions of the cash flow hedges immediately in earnings. We currently have no cash flow hedges. We formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. Due to the application of regulatory accounting principles under FASB ASC Topic 980, gains and losses on derivatives related to SJG's gas purchases are recorded through the Basic Gas Supply Service (BGSS) clause. Initially and on an ongoing basis, we assess whether derivatives designated as hedges are highly effective in offsetting changes in cash flows or fair values of the hedged items. We discontinue hedge accounting prospectively if we decide to discontinue the hedging relationship; determine that the anticipated transaction is no longer likely to occur; or determine that a derivative is no longer highly effective as a hedge. In the event that hedge accounting is discontinued, we will continue to carry the derivative on the balance sheet at its current fair value and recognize subsequent changes in fair value in current period earnings. Unrealized gains and losses on the discontinued hedges that were previously included in Accumulated Other Comprehensive Loss will be reclassified into earnings when the forecasted transaction occurs, or when it is probable that it will not occur. Hedge accounting has been discontinued for all remaining derivatives that were designated as hedging instruments. GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. No impairment charges were recorded during the years ended December 31, 2015, 2014 and 2013. As of both December 31, 2015 and 2014 , $8.9 million related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with Nonutility Property and Equipment and Other Noncurrent Assets on the consolidated balance sheets. TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of December 31, 2015 and 2014 , SJI held 236,571 and 263,578 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI. INCOME TAXES - Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with FASB ASC Topic 740 - “Income Taxes” (See Note 4). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow through method. CASH AND CASH EQUIVALENTS - For purposes of reporting cash flows, highly liquid investments with original maturities of three months or less are considered cash equivalents. IDENTIFIABLE INTANGIBLE ASSETS - Identifiable intangible assets were acquired as part of the acquisition of Energenic projects as discussed in Note 3. The primary identifiable intangible assets of the Company are customer relationships. The Company determines the useful lives of identifiable intangible assets after considering the specific facts and circumstances related to each intangible asset. Considerations may include the contractual term of any agreement related to the asset, the historical performance of the asset, the Company's long-term strategy for using the asset, any laws or other local regulations which could impact the useful life of the asset, and other economic factors, including competition and specific market conditions. Intangible assets that are deemed to have definite lives (finite-lived intangible assets) are amortized, primarily on a straight-line basis, over their useful lives, generally ranging from 2 to 20 years. SJI recorded the cost of identifiable intangible assets of $21.6 million into Noncurrent Assets on the consolidated balance sheets as of December 31, 2015. No amortization has been taken on these assets during 2015. The Company did not have any identifiable intangible assets as of December 31, 2014. GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects as discussed in Note 3. Goodwill represents the excess of the consideration paid over the fair value of identifiable net assets acquired. Goodwill is not amortized, but instead is subject to impairment testing on an annual basis, and between annual tests whenever events or changes in circumstances indicate that the fair value of a reporting unit may be below its carrying amount. The Company recorded $8.9 million of goodwill in Noncurrent Assets on the consolidated balance sheets as of December 31, 2015. No goodwill was recorded on the consolidated balance sheets as of December 31, 2014. NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2015 or 2014 had, or is expected to have, a material impact on the consolidated financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition , and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption. In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis , which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015, with early adoption permitted. The Company does not expect this standard to have a significant impact on its consolidated financial statements upon adoption. In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs . This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. The adoption of this guidance will not have an impact on the Company's financial statement results; however, balance sheet presentations will be modified to conform to this guidance. 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 is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. The Company does not expect this standard to have a significant impact on its consolidated financial statements upon adoption. 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 August 2015, the FASB issued ASU 2015-13, Derivatives and Hedging (Topic 815): Application of the Normal Purchases and Normal Sales Scope Exception to Certain Electricity Contracts within Nodal Energy Markets . This ASU clarifies that for a contract involving the purchase or sale of electricity on a forward basis, companies have the option to elect the normal purchases and normal sales scope exception. Since such contracts meet the physical delivery criterion when the delivery location is within a nodal energy market (i.e., an interconnected electricity grid operated by an independent system operator with established price points at each node or hub location), the ASU notes that it does not constitute net settlement and, consequently, does not cause such a contract to fail to meet the physical delivery criterion. The standard is effective immediately and should be applied prospectively to qualifying contracts existing on August 10, 2015, the date the ASU was issued. The adoption of this standard did not have an impact on the Company's financial statement results. In August 2015, the FASB issued ASU 2015-15, Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements . This ASU states that, given the absence of authoritative guidance for debt issuance costs related to line-of-credit arrangements within ASU 2015-03 (defined above), the SEC staff would not object to an entity deferring and presenting such costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of credit arrangement. The adoption of this standard did not have an impact on the Company's financial statement results. In November 2015, the FASB issued ASU 2015-17, Balance Sheet Classification of Deferred Taxes , which simplifies the presentation of deferred taxes by requiring that deferred tax assets and liabilities be presented as noncurrent on the balance sheet. ASU 2015-17 is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2016. Early adoption is permitted for financial statements that have not been previously issued. ASU 2015-17 may be applied either prospectively to all deferred tax liabilities and assets or retrospectively to all periods presented. The Company adopted this guidance, prospectively, as of December 31, 2015.

STOCK-BASED COMPENSATION PLAN

STOCK-BASED COMPENSATION PLAN	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
STOCK-BASED COMPENSATION PLAN	STOCK-BASED COMPENSATION PLAN: On April 30, 2015, the shareholders of SJI approved the adoption of the Company's 2015 Omnibus Equity Compensation Plan (Plan), replacing the Amended and Restated 1997 Stock-Based Compensation Plan that had terminated on January 26, 2015. Under the Plan, shares may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. No options were granted or outstanding during the years ended December 31, 2015 , 2014 and 2013 . No stock appreciation rights have been issued under the plans. During the years ended December 31, 2015 , 2014 and 2013 , SJI granted 158,929 , 136,526 and 112,928 restricted shares, respectively, to Officers and other key employees under the plans. Performance-based restricted shares vest over a three -year period and are subject to SJI achieving certain market and earnings-based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 200% of the original share units granted. In 2015, SJI also granted time-based shares of restricted stock, one-third of which vests annually over a three -year period and is limited to 100% payout. Vesting of time-based grants is contingent upon SJI achieving a return on equity (ROE) of at least 7% during the initial year of the grant and meeting the service requirement. Provided that the 7% ROE requirement is met in the initial year, payout is solely contingent upon the service requirement being met in years two and three of the grant. In 2015, Officers and other key employees were granted 47,678 shares of time-based restricted stock, which are included in the shares noted above. Grants containing market-based performance targets use SJI's total shareholder return (TSR) relative to a peer group to measure performance. As TSR-based grants are contingent upon market and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant on a straight-line basis over the requisite three-year service 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 per share (EPS) growth rate relative to a peer group to measure performance. Beginning in 2015, earning-based performance targets include predefined EPS and ROE goals to measure performance. As EPS-based and ROE-based grants are contingent upon performance and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant over the requisite three-year period of each award. The fair value is measured as the market price at the date of grant. The initial accruals of compensation expense are based on the estimated number of shares expected to vest, assuming the requisite service is rendered and probable outcome of the performance condition is achieved. That estimate is revised if subsequent information indicates that the actual number of shares is likely to differ from previous estimates. Compensation expense is ultimately adjusted based on the actual achievement of service and performance targets. SJI granted 26,338 , 23,220 and 24,570 restricted shares to Directors in 2015 , 2014 and 2013 , respectively. Shares issued to Directors vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest. The following table summarizes the nonvested restricted stock awards outstanding at December 31, 2015 , and the assumptions used to estimate the fair value of the awards: Grants Shares Outstanding Fair Value Per Share Expected Volatility Risk-Free Interest Rate Officers & Key Employees - 2014 - TSR 51,349 $ 21.31 20.0 % 0.80 % 2014 - EPS 51,349 $ 27.22 N/A N/A 2015 - TSR 34,574 $ 26.31 16.0 % 1.10 % 2015 - EPS, ROE, Time 88,919 $ 29.47 N/A N/A Directors - 2015 26,338 $ 29.21 N/A N/A Expected volatility is based on the actual volatility of SJI’s share price over the preceding three -year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three -year term of the Officers' and other key employees' restricted shares. As notional dividend equivalents are credited to the holders during the three -year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant. The following table summarizes the total stock-based compensation cost for the years ended December 31 (in thousands): 2015 2014 2013 Officers & Key Employees $ 1,128 $ 1,260 $ 2,236 Directors 769 633 765 Total Cost 1,897 1,893 3,001 Capitalized (216 ) (147 ) (237 ) Net Expense $ 1,681 $ 1,746 $ 2,764 The table above reflects the reversal of approximately $1.2 million and $1.1 million of previously recorded costs in 2015 and 2014, respectively. These reversals are associated with EPS-based grants for which performance goals were not met. As of December 31, 2015 , there was $2.9 million of total unrecognized compensation cost related to nonvested share-based compensation awards granted under the restricted stock plans. That cost is expected to be recognized over a weighted average period of 1.8 years. The following table summarizes information regarding restricted stock award activity during 2015 , excluding accrued dividend equivalents: Officers & Other Key Employees Directors Weighted Average Fair Value Nonvested Shares Outstanding, January 1, 2015 223,876 23,220 $ 24.40 Granted 158,929 26,338 $ 28.67 Vested* (91,244 ) (23,220 ) $ 24.57 Cancelled/Forfeited** (65,370 ) — $ 26.56 Nonvested Shares Outstanding, December 31, 2015 226,191 26,338 $ 26.89 *Based on performance information available at the filing of this Report, management does not expect to award shares associated with the 2013 grants to officers and other key employees in 2016. ** Represents shares forfeited as a result of retirements prior to the satisfaction of service conditions. Performance targets during the three-year vesting periods were not attained for the 2011 or 2012 Officer and other key employee grants that vested at December 31, 2013 and 2014, respectively. As a result, no shares were awarded in 2014 or 2015. During the year ended December 31, 2013, SJI awarded 66,077 shares to its Officers and other key employees at a market value of $3.3 million . Also, during the years ended December 31, 2015 , 2014 and 2013 , SJI granted 26,338 , 23,220 and 24,570 shares to its Directors at a market value of $0.8 million , $0.6 million and $0.6 million , respectively. The Company has a policy of issuing new shares to satisfy its obligations under the plans; therefore, there are no cash payment requirements resulting from the normal operation of this plan. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash. At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods. These deferred shares are included in Treasury Stock on the consolidated balance sheets.

AFFILIATIONS AND DISCONTINUED O

AFFILIATIONS AND DISCONTINUED OPERATIONS	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
AFFILIATIONS AND DISCONTINUED OPERATIONS	AFFILIATIONS AND DISCONTINUED OPERATIONS: AFFILIATIONS — The following affiliated entities are accounted for under the equity method: Energenic – US, LLC (Energenic) - Marina and a joint venture partner formed Energenic, in which Marina has a 50% equity interest. Energenic develops and operates on-site, self-contained, energy-related projects. On December 31, 2015, Energenic, Marina and its joint venture partner entered into two Equity Distribution and Purchase Agreements (the "Transaction"), pursuant to which Marina became the sole owner of eight of the Energenic projects ("Marina Projects") and its joint venture partner became the sole owner of seven other Energenic projects ("Partner Projects"). The Transaction has been accounted for as a distribution of member interests by Energenic to its owners and a business combination through the exchange of member interests in various projects between Marina and its joint venture partner. In connection with the distribution, Energenic revalued the projects to fair value, resulting in a net gain of $2.7 million , 50% of which the Company has recognized in Equity in Loss (Earnings) of Affiliated Companies. In connection with the exchange, the joint venture partner also provided a $19.5 million note payable to Marina. The note and other existing obligations of the joint venture partner to Marina (including the note receivable discussed below under LVE Energy Partners and amounts previously included in Notes Receivable - Affiliate) are included in Notes Receivable on the consolidated balance sheets, with approximately $1.8 million being included as a current asset as it is due within one year. This note is collateralized by security interests in various energy project assets owned by the joint venture partner as well as personal guarantees from its principals. As part of the transaction, each party is relieved of any guarantees related to the Projects in which it no longer has an ownership interest. The projects that are now wholly-owned by Marina are ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS & SBS. Through December 31, 2015, Marina’s investment in Energenic has been accounted for under the equity method of accounting. As such, Marina’s share of the equity value of the projects has been included within Investment in Affiliates on the consolidated balance sheets and Marina’s share of the loss or earnings from the projects has been included within Equity in (Loss) Earnings of Affiliated Companies on the statements of consolidated income. As of December 31, 2015, the assets and liabilities of the projects that are now wholly-owned by Marina are consolidated into the consolidated balance sheets. The respective results from operations and cash flows of the projects that are now wholly-owned by Marina will be consolidated into the statements of consolidated income and cash flows beginning in 2016. This transaction represents a non-cash investing and financing activity. The results of the acquired projects will be included in the On-Site Energy Production segment. The following table summarizes the preliminary purchase price allocation and reflects 100% of the fair values of the assets acquired and the liabilities assumed by the Company in connection with the Transaction. The Company is still awaiting final valuation reports supporting the allocation of the purchase price to certain identifiable intangibles. Total consideration for the step acquisition of the remaining interest in the Marina Projects was $46.1 million , which represents the fair value of the Company’s interest in the Partner Projects exchanged ( $31.5 million ) as well as the existing value of the Marina Projects immediately prior to the exchange ( $14.6 million ) (in thousands): Current assets (excluding inventory) $ 7,804 Inventory 3,154 Note Receivable Received 19,504 Fixed Assets 40,854 Intangible Assets: Identifiable Intangibles 21,553 Goodwill 8,880 Non-Current Assets 1,873 Current Liabilities (8,196 ) Note Payable - Affiliate (16,986 ) Long-Term Debt, including current portion (21,457 ) Capital Lease Payable (10,357 ) Other Non-Current Liabilities (572 ) Fair Value of Consolidated Assets and Liabilities of Acquired Projects $ 46,054 The pro forma impact of this transaction on the operations of the Company is not significant. Potato Creek, LLC (Potato Creek) - SJI and a joint venture partner formed Potato Creek, in which SJI has a 30% equity interest. Potato Creek owns and manages the oil, gas and mineral rights of certain real estate in Pennsylvania. PennEast Pipeline Company, LLC (PennEast) - Midstream has a 20% investment in PennEast, which is planning to construct an approximately 100-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, with a target completion of late 2017. LVE Energy Partners, LLC (LVE) - In March 2013, substantially all of the assets of this joint venture, in which Marina had a 50% equity interest, were sold. In 2013, the Company received (a) $57.9 million of repayments of advances to LVE; and (b) a $7.9 million note receivable from a third party, which is recorded in the consolidated balance sheets as of December 31, 2014. As of December 31, 2013, LVE was dissolved and the Company incurred a $0.8 million charge to write-off the remaining interest in 2013. During 2015 , the Company made net investments in unconsolidated affiliates of $18.0 million . During 2014, the Company provided net advances to unconsolidated affiliates of $2.4 million . During 2013, the Company made investments in, and provided net advances to, unconsolidated affiliates of $9.6 million , which does not include the cash proceeds related to the sale of LVE as discussed above. As of December 31, 2015 and 2014 , the outstanding balance of Notes Receivable – Affiliate was $16.4 million and $51.5 million , respectively. As of December 31, 2015, approximately $13.7 million of these notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025 , and the remaining $2.7 million of these notes are unsecured and accrue interest at variable rates. SJI holds significant variable interests in these entities but is not the primary beneficiary. Consequently, these entities are accounted for under the equity method because SJI does not have both a) the power to direct the activities of the entity that most significantly impact the entity’s economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the entity or the right to receive benefits from the entity that could potentially be significant to the entity. As of December 31, 2015 , the Company had a net asset of approximately $17.0 million included in Investment in Affiliates on the consolidated balance sheets related to equity method investees, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of December 31, 2015 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $33.4 million . The following tables present summarized financial information of the total balances for all Affiliates (of which, on average, SJI has only a 50% equity interest) accounted for under the equity method (in thousands): 2015 2014 Current assets $ 21,914 $ 46,683 Noncurrent assets $ 117,091 $ 478,240 Current liabilities $ 47,797 $ 75,260 Noncurrent liabilities $ 112,438 $ 315,801 As of December 31, 2015, the assets and liabilities of the projects that are now wholly owned by Marina as discussed above are consolidated into the consolidated balance sheets. As such, they are not included in the above table. 2015 2014 2013 Revenues $ 163,479 $ 207,031 $ 178,026 Cost of sales $ 86,452 $ 107,042 $ 91,228 (Loss) Income from continuing operations $ (56,962 ) $ (11,666 ) $ 6,229 Net (Loss) Income $ (56,962 ) $ (11,666 ) $ 6,229 The respective results from operations of the projects that are now wholly owned by Marina as discussed above were not consolidated into the statements of consolidated income during 2015. As such, they are included in the above table. DISCONTINUED OPERATIONS - Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (EMI), an SJI subsidiary, which previously operated a fuel oil business. Morie is the former sand mining and processing subsidiary of EMI. EMI sold the common stock of Morie in 1996. SJI conducts tests annually to estimate the environmental remediation costs for these properties. Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts): 2015 2014 2013 Loss before Income Taxes: Sand Mining $ (422 ) $ (620 ) $ (406 ) Fuel Oil (338 ) (274 ) (816 ) Income Tax Benefits 257 312 426 Loss from Discontinued Operations — Net $ (503 ) $ (582 ) $ (796 ) Earnings Per Common Share from Discontinued Operations — Net: Basic and Diluted $ (0.01 ) $ (0.01 ) $ (0.01 )

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES: SJI files a consolidated federal income tax return. State income tax returns are filed on a separate company basis in states where SJI has operations and/or a requirement to file. Total income taxes applicable to operations differ from the tax that would have resulted by applying the statutory Federal income tax rate to pre-tax income for the following reasons (in thousands): 2015 2014 2013 Tax at Statutory Rate $ 37,440 $ 35,727 $ 22,181 Increase (Decrease) Resulting from: State Income Taxes 3,985 1,960 971 ESOP Dividend (1,298 ) (1,232 ) (1,176 ) Amortization of Investment Tax Credits - Utility (149 ) (211 ) (258 ) AFUDC (1,109 ) (1,481 ) (916 ) Investment and Other Tax Credits (37,503 ) (30,661 ) (38,179 ) Other - Net (6 ) 347 (1,637 ) Income Taxes: Continuing Operations 1,360 4,449 (19,014 ) Discontinued Operations (257 ) (312 ) (426 ) Total Income Tax Expense (Benefit) $ 1,103 $ 4,137 $ (19,440 ) The provision for Income Taxes is comprised of the following (in thousands): 2015 2014 2013 Current: Federal $ — $ (62 ) $ (273 ) State (2,352 ) 3,052 3,066 Total Current (2,352 ) 2,990 2,793 Deferred: Federal (4,622 ) 1,707 (19,978 ) State 8,483 (37 ) (1,571 ) Total Deferred 3,861 1,670 (21,549 ) Investment Tax Credit - Utility (149 ) (211 ) (258 ) Income Taxes: Continuing Operations 1,360 4,449 (19,014 ) Discontinued Operations (257 ) (312 ) (426 ) Total Income Tax Expense (Benefit) $ 1,103 $ 4,137 $ (19,440 ) Investment Tax Credits attributable to SJG are deferred and amortized at the annual rate of 3.0% , which approximates the life of related assets. The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax assets and liabilities at December 31 (in thousands): 2015 2014 Deferred Tax Assets: Net Operating Loss Carryforward $ 195,358 $ 157,174 Investment and Other Tax Credits 200,491 154,805 Derivatives / Unrealized Gain 5,652 12,554 Conservation Incentive Program — 2,027 Deferred State Tax 24,833 21,548 Investment Tax Credit Basis Gross-Up — 77 Pension & Other Post Retirement Benefits 29,998 34,892 Deferred Revenues 4,924 11,647 Provision for Uncollectibles 4,200 6,296 Other 6,448 6,734 Total Deferred Tax Asset $ 471,904 $ 407,754 Deferred Tax Liabilities: Book versus Tax Basis of Property $ 675,521 $ 558,960 Deferred Gas Costs - Net 3,998 22,959 Environmental Remediation 19,207 12,147 Deferred Regulatory Costs 566 6,333 Budget Billing - Customer Accounts 830 1,138 Deferred Pension & Other Post Retirement Benefits 42,216 39,891 Conservation Incentive Program 1,132 — Equity In Loss Of Affiliated Companies 9,111 39,230 Other 15,268 13,868 Total Deferred Tax Liability $ 767,849 $ 694,526 Deferred Tax Liability - Net $ 295,945 $ 286,772 Current Deferred Tax Asset $ — $ (57,748 ) Noncurrent Deferred Tax Liability 295,945 344,520 Deferred Tax Liability - Net $ 295,945 $ 286,772 As of December 31, 2015 , SJI has the following federal and state net operating loss carryforwards (in thousands): Net Operating Loss Carryforwards Expire in: Federal State 2031 $ 163,880 $ 45,866 2032 43,724 19,356 2033 68,696 34,940 2034 117,325 28,622 2035 133,782 21,685 $ 527,407 $ 150,469 As of December 31, 2015 , SJI has the following investment tax credit carryforwards (in thousands): Expire in: Investment Tax Credit Carryforward 2030 $ 11,628 2031 26,613 2032 32,071 2033 46,179 2034 38,727 2035 42,548 $ 197,766 SJI has $1.2 million of federal alternative minimum tax credits which have no expiration date. SJI also has research and development credits of $1.4 million that will expire between 2031 and 2034. A valuation allowance is recorded when it is more likely than not that any of SJI's deferred tax assets will not be realized. SJI believes that it will generate sufficient future taxable income to realize the income tax benefits related to SJI's net deferred tax assets. The total unrecognized tax benefits as of December 31, 2015 , 2014 , and 2013 were $0.6 million , $0.6 million , and $0.5 million , respectively, which excludes $0.7 million , $0.7 million , and $0.6 million of accrued interest and penalties, respectively. A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands): 2015 2014 2013 Balance at January 1, $ 552 $ 547 $ 503 Increase as a result of tax positions taken in prior years 7 5 44 Decrease due to a lapse in the statute of limitations — — — Settlements — — — Balance at December 31, $ 559 $ 552 $ 547 The amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate is not significant. The Company's policy is to record interest and penalties related to unrecognized tax benefits as interest expense and other expense, respectively. These amounts were not significant in 2015 , 2014 or 2013 . There have been no significant changes to the unrecognized tax benefits during 2015 , 2014 or 2013 and the Company does not anticipate any significant changes in the total unrecognized tax benefits within the next 12 months. The unrecognized tax benefits are primarily related to an uncertainty of state income tax issues relating to the Company's nexus in certain states. Federal income tax returns from 2012 forward and state income tax returns from 2008 forward are open and subject to examination.

PREFERRED STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
PREFERRED STOCK	PREFERRED STOCK: REDEEMABLE CUMULATIVE PREFERRED STOCK - SJI has 2,500,000 authorized shares of Preference Stock, no par value, which has not been issued.

COMMON STOCK

COMMON STOCK	12 Months Ended
	Dec. 31, 2015
Common Stock [Abstract]
COMMON STOCK	COMMON STOCK: The following shares were issued and outstanding at December 31 (See Note 1): 2015 2014 2013 Beginning of Year 68,334,860 65,430,084 63,306,524 New Issues During Year: Dividend Reinvestment Plan 2,604,424 2,881,556 1,966,834 Stock-Based Compensation Plan 26,338 23,220 156,726 End of Year 70,965,622 68,334,860 65,430,084 The par value ( $1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value at December 31, 2015 of approximately $61.1 million was recorded in Premium on Common Stock. EARNINGS PER COMMON SHARE (EPS) — Basic EPS is based on the weighted-average number of common shares outstanding. The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 195,139 ; 150,062 , and 115,520 shares for the years ended December 31, 2015 , 2014 and 2013 , respectively. These shares relate to SJI’s restricted stock as discussed in Note 2. DIVIDENDS PER SHARE - Dividends per share were $1.02 , $0.96 and $0.90 for the years ended December 31, 2015 , 2014 and 2013 , respectively. DIVIDEND REINVESTMENT PLAN (DRP) —The Company offers a DRP which allows participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases. Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $63.2 million and $80.7 million of equity capital through the DRP during the years ended December 31, 2015 and 2014 , respectively.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2015
Financial Instruments, Owned, at Fair Value [Abstract]
FINANCIAL INSTRUMENTS	FINANCIAL INSTRUMENTS: RESTRICTED INVESTMENTS —Marina is required to maintain escrow accounts related to ongoing capital projects as well as unused loan proceeds pending approval of construction expenditures. As of December 31, 2015 and 2014 , the escrowed proceeds, including interest earned, totaled $3.4 million and $1.7 million , respectively. The Company maintains margin accounts with selected counterparties to support its risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy-related contracts with the respective counterparties decrease. As of December 31, 2015 and 2014 , the balances in these accounts totaled $43.7 million and $63.7 million , respectively. In accordance with a Loan & Security Agreement which ACB has with a third party (see Note 14 - Long-Term Debt), ACB is required to maintain control accounts which include a debt service reserve. As of December 31, 2015, the balance in these accounts totaled $1.7 million . The carrying amounts of the Restricted Investments approximate their fair values at December 31, 2015 and 2014 , which would be included in Level 1 of the fair value hierarchy (See Note 17). INVESTMENT IN AFFILIATES - During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20 -year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex. In June 2014, the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. As of December 31, 2015, the Energenic subsidiaries were providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries had not been able to secure a permanent or long-term energy services agreement with the new owner. As a result, management of the Company and Energenic have evaluated the carrying value of the investment in this project and a related note receivable. Based on the inability of the Energenic subsidiaries to secure a permanent or long-term energy services agreement, the Company r ecorded a $7.7 million (net of tax) no n-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge is included in Equity in Loss of Affiliated Companies for the year ended December 31, 2015 on the statements of consolidated income. Estimating the fair value of an investment is highly judgmental and involves the use of significant estimates and assumptions. Actual results may differ significantly from those used to develop this estimate. The central energy center and energy distribution system owned by the Energenic subsidiaries was financed in part by the issuance of bonds during 2011. These bonds were collateralized primarily by certain assets of the central energy center and revenue from the energy services agreement with the hotel, casino and entertainment complex. During 2015, due to the cessation of normal business operations of the complex and the inability of the Energenic subsidiaries to meet its obligations under the bonds, the trustee for the bondholders filed suit to foreclose on certain assets of the central energy center. In November 2015 during settlement discussions, the bondholders alleged among other things, that they were entitled to recover from Energenic itself, any amounts owed under the bonds that were not covered by the collateral, including principal, interest and attorney’s fees. The bondholders’ assertion was based on inconsistent language in the bond documents. As a result, as of December 31, 2015, management of Energenic has accrued for the cost to settle this claim (See Note 19). The Company's share of this pre-tax charge of $7.5 million is included in Equity in Loss of Affiliated Companies for the year ended December 31, 2015 on the statements of consolidated income. Management of Energenic is currently in active settlement discussions and believes that this amount is recoverable from its insurance carrier and external legal advisors. As of December 31, 2015, the Company, through its investment in Energenic, had a remaining net asset of approximately $1.7 million included in Investment in Affiliates on the consolidated balance sheets related to cogeneration assets for this project. In addition, the Company had approximately $13.7 million included in Notes Receivable - Affiliate on the consolidated balance sheets, due from Energenic, which is secured by those cogeneration assets. This note is subject to a reimbursement agreement that secures reimbursement for the Company, from its joint venture partner, of a proportionate share of any amounts that are not repaid. Management will continue to monitor the situation surrounding the complex and will evaluate the carrying value of the investment and the note receivable as future events occur. NOTE RECEIVABLE - In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey, of which $0.1 million has been repaid. The note bears interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. In December 2015, the borrower exercised its first option to extend the term of the note for an additional three months. SJG holds a first lien security interest on land in Atlantic City as collateral against this note. The carrying amount of this receivable approximates its fair value at December 31, 2015, which would be included in Level 2 of the fair value hierarchy (See Note 17). LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources. The terms of these loans call for customers to make monthly payments over a period of five to ten years with no interest. The carrying amounts of such loans were $12.9 million and $15.0 million as of December 31, 2015 and 2014 , respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.3 million as of both December 31, 2015 and 2014 . The annual amortization to interest is not material to the Company’s consolidated financial statements. The carrying amounts of these receivables approximate their fair value at December 31, 2015 and 2014 , which would be included in Level 2 of the fair value hierarchy (See Note 17). CREDIT RISK - As of December 31, 2015 , approximately $11.7 million or 11.8% of current and noncurrent Derivatives–Energy Related Assets are transacted with one counterparty. This counterparty has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assigned to SJI in the event of default by the counterparty. FINANCE OBLIGATION - During 2010, ACB Energy Partners LLC (ACB), which at the time was a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, completed construction of a combined heat and power generating facility to serve, under an energy services agreement, a thermal plant owned by Marina. Construction period financing was provided by Marina. As substantially all of the costs of constructing the facility were funded by the financing provided by Marina, Marina was considered the owner of the facility for accounting purposes during the construction period. When an entity is considered the accounting owner during the construction period, a sale of the asset effectively occurs when construction of the asset is completed. However, due to its continuing involvement in the facility through its equity interest in Energenic, Marina continued to be considered the owner of the facility for accounting purposes under ASC Topic 360 Property, Plant and Equipment . As a result, as of December 31, 2014, the transaction was accounted for as a financing arrangement under ASC Topic 840 Leases and, therefore, the Company included costs to construct the facility within Nonutility Property, Plant and Equipment on the consolidated balance sheets of $23.7 million as of December 31, 2014 . In addition, the Company included repayments from ACB to Marina on the construction loan within the Finance Obligation on the consolidated balance sheets. Marina does not have a fixed payment obligation to ACB; as a result, the Finance Obligation is classified as a noncurrent liability on the consolidated balance sheets as of December 31, 2014. The costs to construct the facility and the repayments of the construction loan were amortized over the term of the energy services agreement. The impact on the statements of consolidated income was not significant. As a result, the Company recorded $19.7 million , net of amortization, within Finance Obligation on the consolidated balance sheets at December 31, 2014. On December 31, 2015, ACB became a wholly-owned subsidiary of Marina. As a result of this transaction, the facility is no longer accounted for as a financing arrangement and is instead reflected at fair value (see Note 3). As such, the Finance Obligation is no longer recorded on the consolidated balance sheet as of December 31, 2015. FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJI's financial instruments approximate their fair values at December 31, 2015 and 2014 , except as noted below. • For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to SJI at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy, see Note 17 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJI's long-term debt, including current maturities, as of December 31, 2015 and 2014 , were $1,079.0 million and $1,058.5 million , respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of December 31, 2015 and 2014 , was $1,035.8 million and $1,009.4 million , respectively. OTHER FINANCIAL INSTRUMENTS - The carrying amounts of SJI's other financial instruments approximate their fair values at December 31, 2015 and 2014.

SEGMENTS OF BUSINESS

SEGMENTS OF BUSINESS	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
SEGMENTS OF BUSINESS	SEGMENTS OF BUSINESS: SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. These segments are as follows: • Gas utility operations (SJG) consist primarily of natural gas distribution to residential, commercial and industrial customers. • Wholesale energy operations include the activities of SJRG and SJEX. • SJE is involved in both retail gas and retail electric activities. ◦ Retail gas and other operations include natural gas acquisition and transportation service business lines. ◦ Retail electric operations consist of electricity acquisition and transportation to commercial and industrial customers. • On-Site energy production consists of Marina’s thermal energy facility and other energy-related projects. Also included in this segment are the activities of ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS. These entities became wholly-owned subsidiaries of Marina on December 31, 2015 (see Note 3). As such their activities are included only in the Identifiable Assets table below. • Appliance service operations includes SJESP’s servicing of appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. • The activities of Midstream are a part of the Corporate & Services segment. SJI groups its nonutility operations into two categories: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes on-site energy production and appliance service operations. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices. Information about SJI’s operations in different reportable operating segments is presented below (in thousands): 2015 2014 2013 Operating Revenues: Gas Utility Operations $ 534,290 $ 501,875 $ 446,480 Energy Group: Wholesale Energy Operations 129,098 77,048 831 Retail Gas and Other Operations 87,198 127,001 107,748 Retail Electric Operations 150,049 123,773 128,932 Subtotal Energy Group 366,345 327,822 237,511 Energy Services: On-Site Energy Production 63,665 56,129 43,551 Appliance Service Operations 11,186 10,518 13,723 Subtotal Energy Services 74,851 66,647 57,274 Corporate & Services 31,156 30,174 31,286 Subtotal 1,006,642 926,518 772,551 Intersegment Sales (47,074 ) (39,522 ) (41,130 ) Total Operating Revenues $ 959,568 $ 886,996 $ 731,421 2015 2014 2013 Operating Income: Gas Utility Operations $ 119,585 $ 113,690 $ 105,822 Energy Group: Wholesale Energy Operations 35,024 9,493 (37,720 ) Retail Gas and Other Operations (3,218 ) 479 278 Retail Electric Operations 1,042 (466 ) (98 ) Subtotal Energy Group 32,848 9,506 (37,540 ) Energy Services: On-Site Energy Production 2,027 2,560 (2,011 ) Appliance Service Operations 468 362 2,995 Subtotal Energy Services 2,495 2,922 984 Corporate and Services 1,966 1,485 370 Total Operating Income $ 156,894 $ 127,603 $ 69,636 Depreciation and Amortization: Gas Utility Operations $ 58,668 $ 52,155 $ 48,261 Energy Group: Wholesale Energy Operations 435 168 206 Retail Gas and Other Operations 161 83 93 Subtotal Energy Group 596 251 299 Energy Services: On-Site Energy Production 30,242 25,020 15,192 Appliance Service Operations 316 269 261 Subtotal Energy Services 30,558 25,289 15,453 Corporate and Services 1,220 816 877 Total Depreciation and Amortization $ 91,042 $ 78,511 $ 64,890 Interest Charges: Gas Utility Operations $ 19,906 $ 17,872 $ 12,550 Energy Group: Wholesale Energy Operations 441 371 417 Retail Gas and Other Operations 185 267 280 Subtotal Energy Group 626 638 697 Energy Services: On-Site Energy Production 8,169 8,723 4,480 Corporate and Services 11,822 8,803 6,004 Subtotal 40,523 36,036 23,731 Intersegment Borrowings (8,901 ) (6,476 ) (4,906 ) Total Interest Charges $ 31,622 $ 29,560 $ 18,825 2015 2014 2013 Income Taxes: Gas Utility Operations $ 36,945 $ 34,895 $ 34,833 Energy Group: Wholesale Energy Operations 14,410 4,822 (15,070 ) Retail Gas and Other Operations (978 ) 787 434 Retail Electric Operations 426 (190 ) (40 ) Subtotal Energy Group 13,858 5,419 (14,676 ) Energy Services: On-Site Energy Production (49,225 ) (36,404 ) (40,755 ) Appliance Service Operations 186 223 1,237 Subtotal Energy Services (49,039 ) (36,181 ) (39,518 ) Corporate and Services (404 ) 316 347 Total Income Taxes $ 1,360 $ 4,449 $ (19,014 ) Property Additions: Gas Utility Operations $ 218,260 $ 201,737 $ 173,099 Energy Group: Wholesale Energy Operations 382 18 50 Retail Gas and Other Operations 2,053 1,421 702 Subtotal Energy Group 2,435 1,439 752 Energy Services: On-Site Energy Production (1) 139,018 132,214 151,592 Appliance Service Operations 379 84 — Subtotal Energy Services 139,397 132,298 151,592 Corporate and Services 1,902 3,995 3,061 Total Property Additions $ 361,994 $ 339,469 $ 328,504 (1) The property additions for On-Site Energy Production do not include the approximately $40.9 million of Property, Plant and Equipment obtained through the acquisition of eight Energenic projects as discussed in Note 3. 2015 2014 Identifiable Assets: Gas Utility Operations $ 2,288,204 $ 2,185,672 Energy Group: Wholesale Energy Operations 231,660 366,119 Retail Gas and Other Operations 55,111 53,073 Retail Electric Operations 55,528 23,682 Subtotal Energy Group 342,299 442,874 Energy Services: On-Site Energy Production 791,236 675,937 Appliance Service Operations 4,885 3,105 Subtotal Energy Services 796,121 679,042 Discontinued Operations 1,545 1,758 Corporate and Services 653,659 527,691 Intersegment Assets (600,928 ) (487,612 ) Total Identifiable Assets $ 3,480,900 $ 3,349,425

LEASES

LEASES	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
LEASES	LEASES: Marina is considered to be the lessor of certain thermal energy generating property and equipment under an operating lease which expires in May 2027 . As of December 31, 2015 and 2014 the carrying costs of this property and equipment under operating lease was $78.2 million and $79.9 million , respectively, (net of accumulated depreciation of $28.5 million and $25.4 million , respectively) and is included in Nonutility Property and Equipment in the consolidated balance sheets. Minimum future rentals to be received on this operating lease of property and equipment as of December 31, 2015 for each of the next five years and in the aggregate are (in thousands): Year ended December 31, 2016 $ 5,396 2017 5,396 2018 5,396 2019 5,396 2020 5,396 Thereafter 34,626 Total minimum future rentals 61,606 Minimum future rentals do not include additional amounts to be received based on actual use of the leased property. BCLE is considered to be the lessee of certain electric generating units and related facilities and equipment under a capital lease which expires in October 2027. The interest rate related to the obligation is 6.8% , and the related facilities and equipment are amortized over the useful life ranging from 7 - 39 years. As of December 31, 2015, the carrying costs of this property and equipment under capital lease is $4.1 million and is included in Nonutility Property and Equipment in the consolidated balance sheets. Since BCLE became a wholly-owned subsidiary of Marina on December 31, 2015 (see Note 3), there were no carrying costs on the consolidated balance sheets as of December 31, 2014, and no depreciation has been taken on this lease by Marina as of December 31, 2015. Minimum future rentals to be paid on this capital lease of property and equipment as of December 31, 2015 for each of the next five years and in the aggregate are (in thousands): Year ended December 31, 2016 $ 1,282 2017 1,282 2018 1,282 2019 1,282 2020 1,282 Thereafter 8,657 Total minimum future rentals 15,067 Less: Interest portion (4,710 ) Present value of future minimum lease payments $ 10,357

RATES AND REGULATORY ACTIONS

RATES AND REGULATORY ACTIONS	12 Months Ended
	Dec. 31, 2015
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 2010, the BPU granted SJG a base rate increase of $42.1 million , which was predicated, in part, upon an 8.21% rate of return on rate base that included a 10.3% return on common equity. The $42.1 million includes $16.6 million of revenue previously recovered through the Conservation Incentive Program (CIP) and $6.8 million of revenues previously recovered through the Capital Investment Recovery Tracker (CIRT), resulting in incremental revenue of $18.7 million . SJG was permitted to recover regulatory assets contained in its petition and defer certain federally mandated pipeline integrity management program costs for recovery in its next base rate case. In addition, annual depreciation expense was reduced by $1.2 million as a result of the amortization of excess cost of removal recoveries. The BPU also authorized a Phase II of the base rate proceeding to review the costs of CIRT projects not rolled into rate base in the September 2010 settlement. A proceeding took place in 2013 to roll into base rates the remaining $22.5 million of CIRT I project costs that were not included in the 2010 rate increase, as well as CIRT II and III investments totaling $95.0 million that were made subsequent to the 2010 base rate case. These costs were rolled into rate base and reflected in base rates effective October 2013. 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. RATE MECHANISMS - SJG's tariff, a schedule detailing the terms, conditions and rate information applicable to its various types of natural gas service, as approved by the BPU, has several primary rate mechanisms as discussed in detail below: Basic Gas Supply Service (BGSS) Clause - The BGSS price structure allows SJG to recover all prudently incurred gas costs. BGSS charges to customers can be either monthly or periodic (annual). Monthly BGSS charges are applicable to large use customers and are referred to as monthly because the rate changes on a monthly basis pursuant to a BPU-approved formula based on commodity market prices. Periodic BGSS charges are applicable to lower usage customers, which include all of SJG's residential customers, and are evaluated at least annually by the BPU. However, to some extent, more frequent rate changes to the periodic BGSS are allowed. SJG collects gas costs from customers on a forecasted basis and defers periodic over/under recoveries to the following BGSS year, which runs from October 1 through September 30. If SJG is in a net cumulative undercollected position, gas costs deferrals are reflected on the balance sheet as a regulatory asset. If SJG is in a net cumulative overcollected position, amounts due back to customers are reflected on the balance sheet as a regulatory liability. SJG pays interest on net overcollected BGSS balances at the rate of return on rate base utilized by the BPU to set rates in the last base rate proceeding. Regulatory actions regarding the BGSS were as follows: • January 2013 - SJG credited the accounts of its periodic BGSS customers with refunds totaling $9.4 million due to gas costs that were lower than projections. • May 2013 - SJG filed its annual BGSS filing with the BPU requesting a $0.6 million reduction in gas cost recoveries. • September 2013 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $0.6 million reduction in gas cost recoveries. • 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. 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. In October 2006, the BPU approved SJG's CIP as a three -year pilot program. In January 2010, the BPU approved an extension of this program through September 2013, with an automatic one year extension through September 2014 if a request for an extension was filed by March 2013. A petition was filed in March 2013 to extend the CIP program and in May 2014 the BPU approved the continuation of the CIP. 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: • March 2013 - SJG filed a joint petition with another utility requesting modification to, and the continuation of, the CIP program effective October 1, 2013. • May 2013 - SJG made its annual CIP filing with the BPU requesting a reduction in revenue of $17.8 million , which includes a $2.3 million reduction in non-weather related recovery and a $15.5 million reduction in weather related recovery. • September 2013 - The BPU issued an Order approving, on a provisional basis, the 2013-2014 CIP rates filed in May 2013, effective October 1, 2013. • 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. Capital Investment Recovery Tracker (CIRT) - The purpose of the CIRT was to accelerate capital expenditures in an effort to stimulate the economy. The petition requested that SJG be allowed to earn a return of, and a return on, its investment. On a monthly basis during the CIRT year, SJG recorded adjustments to earnings based on actual CIRT program expenditures, as incurred. In September 2013, the BPU approved the base rate roll in of the CIRT I, II and III program investments effective October 1, 2013, resulting in a $15.5 million increase in annual revenue. This approval also concluded Phase II of the 2010 base rate case. All CIRT program investments have been rolled into rate base and the CIRT program is now concluded. Accelerated Infrastructure Replacement Program (AIRP) - In July 2012, SJG filed a petition to implement a five -year, $250.0 million 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 into base rates. Storm Hardening and Reliability Program (SHARP) - In September 2013, SJG filed with the BPU an asset hardening program pursuant to which SJG will invest approximately $280.0 million over seven years to replace low pressure distribution mains and services with high pressure mains and services in coastal areas that are susceptible to flooding during major storm events. Regulatory actions regarding SHARP were as follows: • August 2014 - The BPU approved the SHARP, authorizing SJG to invest $103.5 million over three years for system hardening on barrier islands. SJG will earn on 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. Energy Efficiency Tracker (EET) - In January 2009, SJG filed a petition with the BPU requesting approval of an Energy Efficiency Program (EEP I) for residential, commercial and industrial customers. The BPU approved this petition in July 2009. 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. Regulatory actions regarding the EET/EEP were as follows: • May 2012 - SJG filed a petition requesting the approval of a new Energy Efficiency Program (“EEP II”) and to continue the existing EET to recover all costs associated with the EEP II through a $3.1 million increase in annual revenues. These programs provide customers with increased incentives to reduce their natural gas consumption. In June 2013, the BPU approved the EEP II program in the form of an extension of the existing EEP program, permitting SJG to invest $24.0 million in energy efficiency programs through June 2015. The BPU also approved in June 2013 an extension of the EET with a $2.1 million revenue increase effective July 2013. • June 2012 - SJG filed a petition requesting a continuation of the original EEP Ito bridge the gap between the expiration of the EEP I program on April 30, 2012, and the implementation of the proposed new EEP II program. This petition was approved by the BPU in August 2012. Also in June 2012, SJG filed its 2012 - 2013 annual EET rate adjustment petition requesting a $5.8 million increase in annual revenues to recover the costs associated with its EEP I program. The BPU approved this petition in September 2014. • May 2013 - SJG filed its annual petition requesting an increase of $2.2 million for current EET programs. The BPU approved this petition in September 2014. • May 2014 - SJG filed its annual EET rate adjustment petition requesting an $1.4 million increase in revenues to recover the costs of, and the allowed return on, prior investments associated with energy efficiency programs. The petition is currently pending. • September 2014 - The BPU approved a revenue increase of $2.2 million associated with the 2012-2013 annual EET rate adjustment filing, with rates effective October 1, 2014. • January 2015 - SJG filed a petition with the BPU seeking to continue offering energy efficiency programs through June 2018 with a proposed budget of $56.0 million and with the same rate recovery mechanism that exists for its current energy efficiency programs (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. This petition is currently pending. • August 2015, the BPU approved a two year extension of the Company’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. 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 2013 - SJG made its annual 2013-2014 SBC filing requesting a $6.4 million decrease in SBC revenues. The BPU approved this filing in September 2014. • 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. This petition is currently pending. Remediation Adjustment Clause (RAC) - The RAC recovers environmental remediation costs of 12 former gas manufacturing plants (See Note 15). The BPU allows SJG to recover such costs over seven -year amortization periods. The net between the amounts actually spent and amounts recovered from customers is recorded as a regulatory asset, Environmental Remediation Cost Expended - Net. RAC activity affects revenue and cash flows but does not directly affect earnings because of the cost recovery over seven -year amortization periods. As of December 31, 2015 and 2014 , SJG reflected the unamortized remediation costs of $42.0 million and $29.5 million , respectively, on the consolidated balance sheets under Regulatory Assets (See Note 11). Since implementing the RAC in 1992, SJG has recovered $110.5 million through rates. Clean Energy Program Clause CLEP) - A component of the SBC, the CLEP recovers costs associated with state mandated New Jersey Clean Energy Programs (NJCEP) and, 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 . NJCEP adjustments affect revenue and cash flows but do not directly affect earnings as related costs are deferred and recovered through rates on an on-going basis. Universal Service Fund (USF) - The USF is a statewide program through which funds for the USF and Lifeline Credit and Tenants Assistance Programs are collected from customers of all New Jersey electric and gas utilities. USF adjustments affect cash flows but do not directly affect revenue or earnings as related costs are deferred and recovered through rates on an on-going basis. Separate regulatory actions regarding the USF were as follows: • June 2013 - SJG made its annual USF filing, along with the State’s other electric and gas utilities, proposing to decrease the statewide gas revenues by $29.4 million . This proposal was designed to decrease SJG's annual USF revenue by $3.7 million . • September 2013 - The BPU approved the statewide USF budget of $54.4 million for all the State’s gas utilities. SJG's portion of the total is approximately $5.8 million , which decreased rates effective October 1, 2013, resulting in a $3.4 million decrease to SJG's USF recoveries. • 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. Other Regulatory Matters - Unbundling - In 2000, the BPU approved full unbundling of SJG's system. This allows all natural gas consumers to select their natural gas commodity supplier. As of December 31, 2015 , 35,400 of SJG's customers were purchasing their gas commodity from someone other than SJG. Customers choosing to purchase natural gas from providers other than the utility are charged for the cost of gas by the marketer. The resulting decrease in utility revenues is offset by a corresponding decrease in gas costs. While customer choice can reduce utility revenues, it does not negatively affect SJG's net income or financial condition. The BPU continues to allow for full recovery of prudently incurred natural gas costs through the BGSS. Unbundling did not change the fact that SJG still recovers cost of service, including certain deferred costs, through base rates. Pipeline Integrity Costs - SJG is permitted to defer and recover incremental costs incurred as a result of Pipeline Integrity Management regulations that became effective January 14, 2004, which are aimed at enhancing public safety and reliability. The regulations require that utilities use a comprehensive analysis to assess, evaluate, repair and validate the integrity of certain transmission lines in the event of a leak or failure. As part of SJG's 2014 base rate case, it was permitted to recover previously deferred pipeline integrity costs incurred from October 2010 through June 2014. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in the next base rate proceeding, subject to review by the BPU. As of December 31, 2015 and 2014 , deferred pipeline integrity costs totaled $2.7 million and $3.4 million , respectively, and are included in other regulatory assets (See Note 11). Superstorm Sandy - In June 2013, SJG filed a petition requesting deferral of $0.7 million of incremental operating and maintenance expenses incurred due to Superstorm Sandy. The BPU approved the recovery of these expenses through base rates in SJG’s 2014 base rate case. Filings and petitions described above are still pending unless otherwise indicated.

REGULATORY ASSETS & REGULATORY

REGULATORY ASSETS & REGULATORY LIABILITIES	12 Months Ended
	Dec. 31, 2015
Regulatory Assets and Liabilities Disclosure [Abstract]
REGULATORY ASSETS & REGULATORY LIABILITIES	REGULATORY ASSETS & REGULATORY LIABILITIES: The discussion under Note 10, Rates and Regulatory Actions, is integral to the following explanations of specific regulatory assets and liabilities. Regulatory Assets consisted of the following items (in thousands): December 31, 2015 December 31, 2014 Environmental Remediation Costs: Expended - Net $ 42,032 $ 29,540 Liability for Future Expenditures 123,194 124,308 Deferred Asset Retirement Obligation Costs 42,430 31,584 Deferred Pension and Other Postretirement Benefit Costs 79,779 99,040 Deferred Gas Costs - Net 2,701 32,202 Conservation Incentive Program Receivable 2,624 — Societal Benefit Costs Receivable — 385 Deferred Interest Rate Contracts 7,631 7,325 Energy Efficiency Tracker 496 11,247 Pipeline Supplier Service Charges 3,776 5,441 Pipeline Integrity Cost 4,596 3,431 AFUDC - Equity Related Deferrals 11,423 10,781 Other Regulatory Assets 2,752 1,876 Total Regulatory Assets $ 323,434 $ 357,160 Except where noted below, all regulatory assets are or will be recovered through utility rate charges, as detailed in the following discussion. SJG is currently permitted to recover interest on Environmental Remediation Costs, Societal Benefit Costs Receivable, Energy Efficiency Tracker and Pipeline Integrity Costs, while the other assets are being recovered without a return on investment. Environmental Remediation Costs - SJG has two regulatory assets associated with environmental costs related to the cleanup of 12 sites where SJG or its predecessors previously operated gas manufacturing plants. The first asset, Environmental Remediation Cost: Expended - Net, represents what was actually spent to clean up the sites, less recoveries through the RAC and insurance carriers. These costs meet the deferral requirements of GAAP as the BPU allows SJG to recover such expenditures through the RAC. The other asset, Environmental Remediation Cost: Liability for Future Expenditures, relates to estimated future expenditures required to complete the remediation of these sites. SJG recorded this estimated amount as a regulatory asset with the corresponding current and noncurrent liabilities reflected on the consolidated balance sheets under the captions Current Liabilities and Deferred Credits and Other Noncurrent Liabilities. The BPU allows SJG to recover the deferred costs over seven -year periods after they are spent. Deferred Asset Retirement Obligation (ARO) Costs - This regulatory asset resulted from the recording of ARO and additional utility plant, primarily related to a legal obligation SJG has for certain safety requirements upon the retirement of its gas distribution and transmission system. SJG recovers asset retirement costs through rates charged to customers. All related accumulated accretion and depreciation amounts for these ARO represent timing differences in the recognition of retirement costs that SJG is currently recovering in rates and, as such, SJG is deferring such differences as regulatory assets. Deferred Pension and Other Postretirement Benefit Costs - The BPU authorized SJG to recover costs related to postretirement benefits under the accrual method of accounting consistent with GAAP. Upon the adoption of FASB ASC Topic 715 “Compensation - Retirement Benefits” in 2006, SJG's regulatory asset was increased by $37.1 million representing the recognition of the underfunded positions of SJG's pension and other postretirement benefit plans. Subsequent adjustments to this balance occur annually to reflect changes in the funded positions of these benefit plans caused by changes in actual plan experience as well as assumptions of future experience (See Note 12). Deferred Gas Costs - Net - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability (See Note 10). Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval (See Note 16). Conservation Incentive Program Receivable - The impact of the CIP is recorded as an adjustment to earnings as incurred, while cash recovery under the CIP generally occurs during the subsequent CIP year (see Note 10). Societal Benefit Costs Receivable - This regulatory asset primarily represents cumulative costs less recoveries under the USF and CLEP programs (see Note 10). Deferred Interest Rate Contracts - These amounts represent the market value of interest rate derivatives as discussed further in Note 16. Energy Efficiency Tracker - This regulatory asset represents cumulative investments less recoveries under the Energy Efficiency Program. Pipeline Supplier Service Charges - This regulatory asset represents costs necessary to maintain adequate supply and system pressures, which are being recovered on a monthly basis through the BGSS over the term of the underlying supplier contracts (See Note 10). Pipeline Integrity Cost - As part of SJG's September 2014 base rate increase, SJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2014. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in SJG's next base rate proceeding, subject to review by the BPU (See Note 10). AFUDC Equity Related Deferrals - This regulatory asset represents the future revenue to recover the future income taxes related to the deferred tax liability for the equity component of AFUDC. Included in the balance is $2.3 million which is being recovered over a period of three years as approved by the BPU in SJG’s 2014 rate case settlement. The remaining balance is being amortized over the life of the associated utility plant. Other Regulatory Assets - Some of the assets included in Other Regulatory Assets are currently being recovered from ratepayers as approved by the BPU. Management believes the remaining deferred costs are probable of recovery from ratepayers through future utility rates. Regulatory Liabilities consisted of the following items (in thousands): December 31, 2015 December 31, 2014 Excess Plant Removal Costs $ 32,644 $ 35,940 Societal Benefit Costs Payable 10,197 1,025 Conservation Incentive Program - Payable — 4,700 Other Regulatory Liabilities — 234 Total Regulatory Liabilities $ 42,841 $ 41,899 Excess Plant Removal Costs - Represents amounts accrued in excess of actual utility plant removal costs incurred to date. As part of SJG's September 2014 base rate increase, SJG is required to amortize approximately $1.1 million of this balance to depreciation expense each year. Societal Benefit Costs Payable - This regulatory liability primarily represents cumulative costs less recoveries under the USF and CLEP programs. See previous discussion under "Societal Benefit Costs Receivable" above. Conservation Incentive Program - Payable - See previous discussion under "Conservation Incentive Program - Receivable" above. Other Regulatory Liabilities - All other regulatory liabilities are subject to being returned to ratepayers in future rate proceedings.

PENSION AND OTHER POSTRETIREMEN

PENSION AND OTHER POSTRETIREMENT BENEFITS	12 Months Ended
	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
PENSION AND OTHER POSTRETIREMENT BENEFITS	PENSION AND OTHER POSTRETIREMENT BENEFITS: SJI has several defined benefit pension plans and other postretirement benefit plans. Approximately 43.0% of the Company's current, full-time, regular employees will be entitled to annuity payments upon retirement. Participation in the Company's qualified defined benefit pension plans was closed to new employees beginning in 2003; however, employees who are not eligible for these pension plans are eligible to receive an enhanced version of SJI's defined contribution plan. Certain SJI officers also participate in a non-funded supplemental executive retirement plan (SERP), a non-qualified defined benefit pension plan. The other postretirement benefit plans provide health care and life insurance benefits to some retirees. Net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands): Pension Benefits 2015 2014 2013 Service Cost $ 5,337 $ 4,510 $ 5,421 Interest Cost 11,168 10,735 9,439 Expected Return on Plan Assets (14,789 ) (13,491 ) (11,914 ) Amortizations: Prior Service Cost 212 175 251 Actuarial Loss 10,608 5,716 9,006 Net Periodic Benefit Cost 12,536 7,645 12,203 Capitalized Benefit Costs (4,805 ) (3,047 ) (5,002 ) Deferred Benefit Costs (1,007 ) — — Total Net Periodic Benefit Expense $ 6,724 $ 4,598 $ 7,201 Other Postretirement Benefits 2015 2014 2013 Service Cost $ 1,116 $ 891 $ 1,139 Interest Cost 2,973 2,852 2,730 Expected Return on Plan Assets (2,993 ) (2,603 ) (2,378 ) Amortizations: Prior Service Cost (Credits) 608 152 (283 ) Actuarial Loss 1,342 974 1,738 Net Periodic Benefit Cost 3,046 2,266 2,946 Capitalized Benefit Costs (1,043 ) (722 ) (1,172 ) Deferred Benefit Costs (256 ) — — Total Net Periodic Benefit Expense $ 1,747 $ 1,544 $ 1,774 Capitalized benefit costs reflected in the table above relate to SJG’s construction program. Deferred benefit costs relate to the deferral of incremental expenses associated with the adoption of new mortality tables (RP-2014 base table with MP-2014 generational projection scale) in 2015. Deferred benefit costs are expected to be recovered through rates as part of SJG's next base rate case. Companies with publicly traded equity securities that sponsor a postretirement benefit plan are required to fully recognize, as an asset or liability, the overfunded or underfunded status of its benefit plans and recognize changes in the funded status in the year in which the changes occur. Changes in funded status are generally reported in Other Comprehensive Loss; however, since SJG recovers all prudently incurred pension and postretirement benefit costs from its ratepayers, a significant portion of the charges resulting from the recording of additional liabilities under this requirement are reported as regulatory assets (See Note 11). Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands): Regulatory Assets Accumulated Other Comprehensive Loss (pre-tax) Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Balance at January 1, 2014 $ 42,632 $ 16,652 $ 27,574 $ 3,710 Amounts Arising during the Period: Net Actuarial Loss 31,075 7,826 14,698 2,269 Prior Service Cost 486 4,146 14 981 Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (2,841 ) (628 ) (2,819 ) (187 ) Prior Service (Cost) Credit (175 ) (133 ) 1 (18 ) Balance at December 31, 2014 71,177 27,863 39,468 6,755 Amounts Arising during the Period: Net Actuarial (Loss)/Gain (463 ) (3,155 ) 59 (2,285 ) Prior Service Credit — (499 ) — (106 ) Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (6,079 ) (1,107 ) (4,452 ) (221 ) Prior Service Cost (203 ) (7,755 ) (9 ) (2,081 ) Balance at December 31, 2015 $ 64,432 $ 15,347 $ 35,066 $ 2,062 The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2016 are as follows (in thousands): Pension Benefits Other Postretirement Benefits Prior Service Cost/(Credit) $ 203 $ (257 ) Net Actuarial Loss $ 5,488 $ 998 The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2016 are as follows (in thousands): Pension Benefits Other Postretirement Benefits Prior Service Cost/(Credit) $ 9 $ (88 ) Net Actuarial Loss $ 3,747 $ 179 A reconciliation of the plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in SJI's consolidated balance sheets follows (in thousands): Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 Change in Benefit Obligations: Benefit Obligation at Beginning of Year $ 265,434 $ 216,395 $ 75,592 $ 62,355 Service Cost 5,337 4,510 1,116 891 Interest Cost 11,168 10,735 2,973 2,852 Actuarial (Gain) Loss (17,349 ) 42,746 (8,591 ) 8,151 Retiree Contributions — — 700 488 Plan Amendments — 550 (9,899 ) 5,143 Benefits Paid (10,395 ) (9,502 ) (4,461 ) (4,288 ) Benefit Obligation at End of Year $ 254,195 $ 265,434 $ 57,430 $ 75,592 Change in Plan Assets: Fair Value of Plan Assets at Beginning of Year $ 180,523 $ 178,093 $ 43,222 $ 41,653 Actual Return on Plan Assets (2,321 ) 10,397 (423 ) 596 Employer Contributions 17,017 1,535 8,721 4,773 Retiree Contributions — — 700 488 Benefits Paid (10,395 ) (9,502 ) (4,461 ) (4,288 ) Fair Value of Plan Assets at End of Year $ 184,824 $ 180,523 $ 47,759 $ 43,222 Funded Status at End of Year: $ (69,371 ) $ (84,911 ) $ (9,671 ) $ (32,370 ) Amounts Related to Unconsolidated Affiliate 204 57 509 301 Accrued Net Benefit Cost at End of Year $ (69,167 ) $ (84,854 ) $ (9,162 ) $ (32,069 ) Amounts Recognized in the Statement of Financial Position Consist of: Current Liabilities $ (2,261 ) $ (1,550 ) $ — $ — Noncurrent Liabilities (66,906 ) (83,304 ) (9,162 ) (32,069 ) Net Amount Recognized at End of Year $ (69,167 ) $ (84,854 ) $ (9,162 ) $ (32,069 ) Amounts Recognized in Regulatory Assets Consist of: Prior Service Costs $ 741 $ 944 $ (3,289 ) $ 4,965 Net Actuarial Loss 63,691 70,233 18,636 22,898 $ 64,432 $ 71,177 $ 15,347 $ 27,863 Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax): Prior Service Costs $ 77 $ 86 $ (1,074 ) $ 1,113 Net Actuarial Loss 34,989 39,382 3,136 5,642 $ 35,066 $ 39,468 $ 2,062 $ 6,755 The projected benefit obligation (PBO) and accumulated benefit obligation (ABO) of SJI's qualified employee pension plans were $207.7 million and $191.9 million , respectively, as of December 31, 2015 ; and $219.7 million and $201.0 million , respectively, as of December 31, 2014 . The ABO of these plans exceeded the value of the plan assets as of December 31, 2015 and 2014. The value of these assets were $184.8 million and $180.5 million as of December 31, 2015 and 2014 , respectively, and can be seen in the table above. The PBO and ABO for SJI's non-funded SERP were $46.5 million and $45.0 million , respectively, as of December 31, 2015 ; and $45.7 million and $44.5 million , respectively, as of December 31, 2014 . 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 2015 2014 2015 2014 Discount Rate 4.83 % 4.25 % 4.73 % 4.20 % 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 2015 2014 2013 2015 2014 2013 Discount Rate 4.25 % 5.09 % 4.26 % 4.20 % 4.91 % 4.14 % Expected Long-Term Return on Plan Assets 7.75 % 7.75 % 7.50 % 6.25 % 6.25 % 6.60 % Rate of Compensation Increase 3.50 % 3.50 % 3.25 % 3.50 % 3.50 % 3.25 % In 2014, the Society of Actuaries (SOA) released new mortality tables (RP-2014 base table with MP-2014 generational projection scale), which indicated that the average life expectancy of both active and retired plan participants had increased. Obligations as of December 31, 2014, disclosed herein reflect the use of those new tables. In 2015, the SOA released an update to the RP-2014 tables (MP-2015 base tables), slightly reducing the average life expectancy previously released. The obligations as of December 31, 2015, disclosed herein, reflect the use of the updated 2015 tables. While the adoption of the new tables impacts liabilities significantly as of December 31of the year of adoption, the impact on expense did not occur until the subsequent year. The discount rates used to determine the benefit obligations at December 31, 2015 and 2014 , 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 assumed health care cost trend rates at December 31 were: 2015 2014 Medical Care and Drug Cost Trend Rate Assumed for Next Year N/A 7.00 % Dental Care Cost Trend Rate Assumed for Next Year N/A 4.75 % Rate to which Cost Trend Rates are Assumed to Decline (the Ultimate Trend Rate) N/A 4.75 % Year that the Rate Reaches the Ultimate Trend Rate N/A 2023 The retiree medical plan changed effective January 1, 2016. Retirees are provided a fixed contribution to a health reimbursement account, allowing them to obtain coverage from health-care exchanges, rather than utilizing the Company provided health-care plan. Since the health-care benefits are now a fixed dollar amount under the new plan and will not increase in the future, the plan no longer has health care trend assumptions as of December 31, 2015. As a result, assumed health care cost trend rates no longer have a significant effect on the amounts reported for SJI's postretirement health care plans. A one-percentage-point change in assumed health care cost trend rates would have the following effects (in thousands): 1-Percentage- Point Increase 1-Percentage- Point Decrease Effect on the Total of Service and Interest Cost $ 199 $ (160 ) 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 - 14 percent to all other types of investments. Equity securities include investments in commingled common/collective trust funds as well as large-cap and mid-cap companies. Fixed income securities include commingled common/collective trust funds, group annuity contracts for pension payments, and hedge funds. Other types of investments include investments in private equity funds and real estate funds that follow several different strategies. The strategy recognizes that risk and volatility are present to some degree with all types of investments. We seek to avoid high levels of risk at the total fund level through diversification by asset class, style of manager, and sector and industry limits. Specifically prohibited investments include, but are not limited to, venture capital, margin trading, commodities and securities of companies with less than $250.0 million capitalization (except in the small-cap portion of the fund where capitalization levels as low as $50.0 million are permissible). These restrictions are only applicable to individual investment managers with separately managed portfolios and do not apply to mutual funds or commingled trusts. SJI evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2015 . 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, 2015 , there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in SJI's pension and other postretirement benefit plan assets. GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. This hierarchy groups assets into three distinct levels, as fully described in Note 17, which will serve as the basis for presentation throughout the remainder of this Note. The fair values of SJI's pension plan assets at December 31, 2015 and 2014 by asset category are as follows (in thousands): Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015 Cash / Cash Equivalents: Cash $ 35 $ 35 $ — $ — Common/Collective Trust Funds (a) 858 — 858 — STIF-Type Instrument (b) 1,360 — 1,360 — Equity securities: Common/Collective Trust Funds - U.S. (a) 52,058 — 52,058 — Common/Collective Trust Funds - International (a) 33,236 — 33,236 — U.S. Large-Cap (c) 14,305 14,305 — — U.S. Mid-Cap (c) 3,407 3,407 — — U.S. Small-Cap (c) 260 260 — — International (c) 1,695 1,695 — — Fixed Income: Common/Collective Trust Funds (a) 50,664 — 50,664 — Guaranteed Insurance Contract (d) 9,960 — — 9,960 Hedge Funds (e) 4,159 — — 4,159 Other types of investments: Private Equity Fund (f) 4,312 — — 4,312 Common/Collective Trust Fund - Real Estate (g) 8,515 — — 8,515 Total $ 184,824 $ 19,702 $ 138,176 $ 26,946 Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2014 Cash / Cash Equivalents: Common/Collective Trust Funds (a) $ 692 $ — $ 692 $ — STIF-Type Instrument (b) 1,252 — 1,252 — Equity securities: Common/Collective Trust Funds - U.S. (a) 51,197 — 51,197 — Common/Collective Trust Funds - International (a) 30,963 — 30,963 — U.S. Large-Cap (c) 12,961 12,961 — — U.S. Mid-Cap (c) 5,147 5,147 — — U.S. Small-Cap (c) 232 232 — — International (c) 3,369 3,369 — — Fixed Income: Common/Collective Trust Funds (a) 48,375 — 48,375 — Guaranteed Insurance Contract (d) 10,912 — — 10,912 Hedge Funds (e) 4,331 — — 4,331 Other types of investments: Private Equity Fund (f) 3,616 — — 3,616 Common/Collective Trust Fund - Real Estate (g) 7,476 — — 7,476 Total $ 180,523 $ 21,709 $ 132,479 $ 26,335 (a) This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable. Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments. (b) This category represents short-term investment funds held for the purpose of funding disbursement payment arrangements. Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information. Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments. (c) This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy. These common stocks are actively traded on exchanges and price quotes for these shares are readily available. These common stocks are classified as Level 1 investments. (d) This category represents SJI's Group Annuity contracts with a nationally recognized life insurance company. The contracts are the assets of the plan, while the underlying assets of the contracts are owned by the contract holder. Valuation is based on a formula and calculation specified within the contract. Since the valuation is based on the reporting entity's own assumptions, these contracts are classified as Level 3 investments. (e) This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments. (f) This category represents a limited partnership/commingled trust which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 to 120 day lag and, therefore, the value reported herein represents the market value as of June 30 or September 30, 2015 and 2014, respectively, with cash flow changes through December applied. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments. Fund investments are illiquid and resale is restricted. These funds are classified as Level 3 investments. (g) This category represents real estate common/collective trust fund investments through a commingled employee benefit trust. These commingled funds are part of a direct investment in a pool of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals from sources with professional qualifications. Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments. Fair Value Measurement Using Significant Unobservable Inputs (Level 3) (In thousands) Guaranteed Private Insurance Hedge Equity Real Contract Funds Funds Estate Total Balance at January 1, 2014 $ 11,322 $ 4,154 $ 3,046 $ 6,741 $ 25,263 Actual return on plan assets: Relating to assets still held at the reporting date 498 177 (24 ) 735 1,386 Relating to assets sold during the period 13 — 325 — 338 Purchases, Sales and Settlements (921 ) — 269 — (652 ) Balance at December 31, 2014 10,912 4,331 3,616 7,476 26,335 Actual return on plan assets: Relating to assets still held at the reporting date (106 ) (172 ) (302 ) 1,039 459 Relating to assets sold during the period 25 — 429 — 454 Purchases, Sales and Settlements (871 ) — 569 — (302 ) Balance at December 31, 2015 $ 9,960 $ 4,159 $ 4,312 $ 8,515 $ 26,946 As with the pension plan assets, the Company's overall investment strategy for post-retirement benefit plan assets is to achieve a diversification by asset class, style of manager, and sector and industry limits to achieve investment results that match the actuarially assumed rate of return, while preserving the inflation adjusted value of the plans. The Company has implemented this diversification strategy with a mix of common/collective trust funds, mutual funds and Company-owned life insurance policies. The target allocations for post-retirement benefit plan assets are 30 - 43 percent U.S. equity securities, 20 - 30 percent international equity securities, and 32 - 42 percent fixed income investments and 0 - 7 percent to all other types of investments. Equity securities include investments in large-cap, mid-cap and small-cap companies within mutual funds or common/collective trust funds. Fixed income securities within the common/collective trust fund include primarily investment grade, U.S. Government and mortgage-backed financial instruments. The insurance policies are backed by a series of commingled trust investments held by the insurance carrier. The fair values of SJI's other postretirement benefit plan assets at December 31, 2015 and 2014 by asset category are as follows (in thousands): Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015: Cash $ 26 $ 26 $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) $ 13,522 $ — $ 13,522 $ — Common/Collective Trust Funds - International (a) 8,313 — 8,313 — Mutual Fund - U.S. (b) 1,309 1,309 — — Mutual Funds - International (b) 983 983 — — Fixed Income: Common/Collective Trust Funds - Bonds (a) 13,187 — 13,187 — Mutual Funds - Bonds (b) 1,441 1,441 — — Other Types of Investments: Mutual Funds - REITS (b) 152 152 — — Company Owned Life Insurance (c) 8,826 — 8,826 — Total $ 47,759 $ 3,911 $ 43,848 $ — Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2014: Cash $ 153 $ 153 $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) $ 10,493 $ — $ 10,493 $ — Common/Collective Trust Funds - International (a) 7,373 — 7,373 — Mutual Fund - U.S. (b) 4,723 4,723 — — Mutual Funds - International (b) 1,795 1,795 — — Fixed Income: Common/Collective Trust Funds - Bonds (a) 11,597 — 11,597 — Mutual Funds - Bonds (b) 2,820 2,820 — — Other Types of Investments: Mutual Funds - REITS (b) 308 308 — — Company Owned Life Insurance (c) 3,960 — 3,960 — Total $ 43,222 $ 9,799 $ 33,423 $ — (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 2016 $ 11,409 $ 4,458 2017 $ 11,846 $ 4,427 2018 $ 12,376 $ 4,363 2019 $ 13,374 $ 4,406 2020 $ 13,954 $ 4,519 2021 - 2024 $ 82,139 $ 21,933 CONTRIBUTIONS - SJI contributed $15.0 million and $12.7 million to the pension plans in 2015 and 2013, respectively, with no pension contribution made in 2014. Payments related to the unfunded SERP plan in 2015, 2014, and 2013 were $2.0 million , $1.5 million and $1.3 million , respectively. SERP payments are expected to approximate $2.3 million in 2016. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to its other postretirement benefit plans’ trusts, less costs incurred directly by SJG. DEFINED CONTRIBUTION PLAN - SJI offers an Employees' Retirement Savings Plan (Savings Plan) to eligible employees. For employees eligible for participation in SJI's defined benefit pension plan, SJI matches 50% of participants' contributions up to 6% of base compensation. For employees who are not eligible for participation in SJI's defined benefit pension plans, SJI matches 50% of participants' contributions up to 8% of base compensation. Employees not eligible for the pension plans also receive a year-end contribution of $1,500 , if 10 or fewer years of service, or $2,000 , if more than 10 years of service. The amount expensed and contributed for the matching provision of the Savings Plan approximated $2.1 million , $2.0 million and $1.7 million for the years ended December 31, 2015 , 2014 and 2013 , respectively.

LINES OF CREDIT

LINES OF CREDIT	12 Months Ended
	Dec. 31, 2015
Line of Credit Facility [Abstract]
LINES OF CREDIT	LINES OF CREDIT: Credit facilities and available liquidity as of December 31, 2015 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 136,600 (A) $ 63,400 May 2018 Uncommitted Bank Lines 10,000 — 10,000 August 2016 Total SJG 210,000 136,600 73,400 SJI: Revolving Credit Facility 400,000 305,400 (B) 94,600 February 2018 Total SJI 400,000 305,400 94,600 Total $ 610,000 $ 442,000 $ 168,000 (A) Includes letters of credit outstanding in the amount of $2.2 million . (B) Includes letters of credit outstanding in the amount of $8.1 million . The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.13% , 0.83% and 1.04% at December 31, 2015 , 2014 and 2013 , respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2015 and 2014 were $335.0 million and $267.0 million , respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2015 and 2014 were $471.1 million and $390.7 million , respectively. The SJI and SJG facilities are provided by a syndicate of banks and contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements) to not more than 0.65 to 1 , measured at the end of each fiscal quarter. SJI and SJG were in compliance with this covenant as of December 31, 2015 . SJG has a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million . The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes. SJG uses the commercial paper program in tandem with the new $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million .

LONG-TERM DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT: Outstanding Long-Term Debt at December 31 consisted of the following: 2015 2014 Long-Term Debt (A): South Jersey Gas Company: First Mortgage Bonds: (B) 5.387% Series due 2015 (C) $ — $ 10,000 5.437% Series due 2016 10,000 10,000 4.6% Series due 2016 17,000 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 50,000 50,000 3.03% Series due 2024 35,000 35,000 3.63% Series due 2025 (D) 9,091 10,000 4.84% Series due 2026 15,000 15,000 4.93% Series due 2026 45,000 45,000 4.03% Series due 2027 45,000 45,000 4.01% Series due 2030 50,000 50,000 4.23% Series due 2030 30,000 30,000 3.74% Series due 2032 35,000 35,000 5.55% Series due 2033 32,000 32,000 6.213% Series due 2034 10,000 10,000 5.45% Series due 2035 10,000 10,000 Series A 2006 Bonds at variable rates due 2036 (E) 24,900 25,000 SJG Term Facility (F) 139,000 59,000 Marina Energy LLC: (G) Series A 2001 Bonds at variable rates due 2031 20,000 20,000 Series B 2001 Bonds at variable rates due 2021 25,000 25,000 Series A 2006 Bonds at variable rates due 2036 16,400 16,400 South Jersey Industries: 2.39% Series A 2012 Notes due 2015 (H) — 64,000 2.71% Series B 2012 Notes due 2017 16,000 16,000 3.05% Series due 2019 (I) 60,000 60,000 3.05% Series due 2019 (I) 30,000 30,000 3.05% Series due 2019 (I) 50,000 50,000 3.46% Series C 2012 Notes due 2022 35,000 35,000 Series Notes at variable rates due 2019 (I) 40,000 40,000 Series Notes at variable rates due 2019 (I) 60,000 60,000 South Jersey Industries Term Loan at variable rates due 2015 (J) — 50,000 South Jersey Industries Term Loan at variable rates due 2020 (J) 50,000 — ACB Energy Partners, LLC: 7.60 % Loan & Security Agreement (K) 12,735 — Other Energy Project Debt (L): 4.83 % ACLE 3,551 — 4.83 % SCLE 1,738 — 4.83 % SXLE 3,433 — Total Long-Term Debt Outstanding $ 1,035,848 $ 1,009,400 Less Current Maturities (29,454 ) (149,909 ) Total Long-Term Debt $ 1,006,394 $ 859,491 (A) Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2016, $29,454 ; 2017, $172,558 ; 2018, $40,667 ; 2019, $260,783 ; and 2020, $74,476 . (B) The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant. (C) In August 2015, SJG retired $10.0 million aggregate principal amount of 5.387% Medium Term Notes (MTN's) at maturity. (D) In December 2015, SJG paid $0.9 million toward the principal amount of 3.63% MTN's due December 2025. (E) In September 2015, SJG paid $0.1 million toward the principal amount of variable rate demand bonds due February 2036. These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2015 was 0.03% . 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. (F) In June 2014, SJG entered into a $200.0 million multiple-draw term facility offered by a syndicate of banks which expires in June 2017. SJG can draw under this facility through June 2016 and this facility bears 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. (G) Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2015 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.04% , 0.47% and 0.04% respectively. The interest rate on all but $39.0 million of the bonds has been effectively fixed via interest rate swaps at 4.22% until January 2026. These bonds contain no financial covenants. Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in March, 2016. The Company has plans to renew this letter of credit facility upon expiration. (H) In June 2015, SJI redeemed at maturity $64.0 million aggregate principal amount of 2.39% Senior Notes. (I) In June 2014, SJI entered into a Note Purchase Agreement that provided for SJI to issue an aggregate of $240.0 million of medium term notes, all of which were issued as follows: (a) in June 2014, SJI issued $60.0 million aggregate principal amount of 3.05% Senior Notes due June 2019, and $40.0 million aggregate principal amount of Floating Rate Senior Notes due June 2019; (b) in August 2014, SJI issued $30.0 million aggregate principal amount of 3.05% Senior Notes due August 2019; and (c) in September 2014, SJI issued $50.0 million aggregate principal amount of 3.05% Senior Notes due September 2019, and $60.0 million aggregate principal amount of Floating Rate Senior Notes due September 2019. At December 31, 2015 , the floating rate was 1.93% . (J) In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million , which matures in October 2020. This agreement replaced existing facilities that expired in October 2015. The variable rate at December 31, 2015 was 1.28% . (K) ACB has a Loan and Security Agreement (“LSA”) with a third party to borrow up to $16.0 million . Under the LSA, ACB pays principal and interest (at a fixed rate of 7.60% ) in equal quarterly installments that began in February 2011 and run through February 2021. As of December 31, 2014, ACB was a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest. In December 2015, ACB became a wholly-owned subsidiary of Marina (see Note 3); as such, the remaining outstanding debt of $12.7 million is included on the consolidated balance sheets as of December 31, 2015. The remaining debt was paid in January 2016 (see Note 19). (L) ACLE, SCLE and SXLE (the "Other Energy Projects") have long-term debt agreements with a third party to borrow up to $10.0 million . Under the debt agreement, the Other Energy Projects pay principal and interest (at a fixed rate of 4.83% ) in equal installments that began December 2013 and run through December 2020. As of December 31, 2014, the Other Energy Projects were wholly-owned subsidiaries of Energenic, of which Marina had a 50% equity interest. SJI had agreements to guarantee 50% of the outstanding debt, which was $4.7 million as of December 31, 2014, and the Company had recorded $0.3 million for the fair value of the guarantees on the consolidated balance sheets as of December 31, 2014. In December 2015, the Other Energy Projects became wholly-owned subsidiaries of Marina (see Note 3); as such, the remaining outstanding debt of $8.7 million is included on the consolidated balance sheets as of December 31, 2015. In December 2015, SJG filed a petition with the New Jersey Board of Public Utilities 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 is pending approval.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES: GAS SUPPLY CONTRACTS - In the normal course of business, SJG and SJRG have entered into long-term contracts for natural gas supplies, firm transportation and gas storage service. The transportation and storage service agreements with interstate pipeline suppliers were made under FERC approved tariffs. SJRG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services is approximately $0.5 million per month. SJG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services averages approximately $6.3 million per month and is recovered on a current basis through the BGSS. SJRG has also committed to purchase a minimum of 626,500 dts/d and up to 796,250 dts/d of natural gas, from various suppliers, for terms ranging from three to ten years at index based prices. PENDING LITIGATION - The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain gas supply and capacity management contract disputes and certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.2 million and $2.9 million related to all claims in the aggregate as of December 31, 2015 and 2014 , 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 45.0% of our workforce at December 31, 2015 . The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76. SJG and SJESP employees represented by the IBEW operate under collective bargaining agreements that run through February 2017. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017. GUARANTEES - As of December 31, 2015 , SJI, the parent company, has issued guarantees to third parties on behalf of its consolidated subsidiaries. These guarantees were issued to guarantee payment to third parties with whom SJI's consolidated subsidiaries have commodity supply contracts and for Marina's construction and operating activities. As of December 31, 2015 , these guarantees support future firm commitments of SJI's consolidated subsidiaries and $79.3 million of the Accounts Payable already recorded on SJI's consolidated balance sheet. As part of the acquisition of Energenic projects (see Note 3), the Company is relieved of any guarantees from prior periods related to the projects in which it no longer has an ownership interest. As of December 31, 2015 , SJI had issued $5.2 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas. STANDBY LETTERS OF CREDIT — As of December 31, 2015 , SJI provided $8.1 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. SJG provided a $2.2 million letter of credit under its revolving credit facility to support the remediation of environmental conditions at certain locations in SJG's service territory. The Company has also provided $87.5 million of additional letters of credit under separate facilities outside of the revolving credit facilities to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project. ENVIRONMENTAL REMEDIATION COSTS — SJI incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. SJI and some of its nonutility subsidiaries also recorded costs for environmental cleanup of sites where SJF previously operated a fuel oil business and Morie maintained equipment, fueling stations and storage. SJI successfully entered into settlements with all of its historic comprehensive general liability carriers regarding the environmental remediation expenditures at the SJG sites. Also, SJG had purchased a Cleanup Cost Cap Insurance Policy limiting the amount of remediation expenditures that SJG was required to make at 11 of its sites. This policy provided coverage up to $50.0 million , which was exhausted in 2012. Since the early 1980s, SJI accrued environmental remediation costs of $377.2 million , of which $250.6 million was spent as of December 31, 2015 . The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands): 2015 2014 Beginning of Year $ 128,172 $ 123,429 Accruals 19,489 18,533 Expenditures (21,038 ) (13,790 ) End of Year $ 126,623 $ 128,172 The balances are segregated between current and noncurrent on the consolidated balance sheets under the captions Current Liabilities and Deferred Credits and Other Noncurrent Liabilities. Management estimates that undiscounted future costs to clean up SJG's sites will range from $123.2 million to $204.7 million . Six of SJG's sites comprise the majority of these estimates, the sum of the six sites range from a low of $110.5 million to a high of $190.5 million . SJG recorded the lower end of this range as a liability because a single reliable estimation point is not feasible due to the amount of uncertainty involved in the nature of projected remediation efforts and the long period over which remediation efforts will continue. Recorded amounts include estimated costs based on projected investigation and remediation work plans using existing technologies. Actual costs could differ from the estimates due to the long-term nature of the projects, changing technology, government regulations and site-specific requirements. Significant risks surrounding these estimates include unforeseen market price increases for remedial services, property owner acceptance of remedy selection, regulatory approval of selected remedy and remedial investigative findings. The remediation efforts at SJG's six most significant sites include the following: Site 1 - Several interim remedial actions have been completed at the site. Steps remaining to remediate the balance of the site include selection of the remedial action, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy 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 proposed to the regulatory authority. Steps remaining to remediate the site include confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy 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 and issuance of a Response Action Outcome. Site 4 - Remedial investigation activities are complete at this site and a final remedy has been proposed to and 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 -Remedial investigation activities are complete at this site and a final remedy has been proposed to and approved by the regulatory authority. Steps remaining to remediate the site include in-situ remediation of impacted soil, post remediation groundwater monitoring, and issuance of a Response Action Outcome. Site 6 - Remedial investigation activities have been completed at this site and a final site remedy is being developed for proposal to the regulatory authority. Steps remaining to remediate the site include selection of a final remedy, confirmation of regulatory compliance of the selected remedy, implementation of the approved remedy and issuance of a Response Action Outcome. With Morie's sale in 1996, EMI assumed responsibility for environmental liabilities currently estimated between $2.8 million and $4.2 million . The information available on these sites is sufficient only to establish a range of probable liability and no point within the range is more likely than any other. Therefore, EMI has accrued the lower end of the range. Changes in the accrual are included in the statements of consolidated income under Loss from Discontinued Operations. SJI and SJF estimate their potential exposure for the future remediation of six sites where fuel oil operations existed years ago to range from $0.6 million to $1.3 million . The lower end of this range has been recorded under Current Liabilities and Deferred Credits and Other Noncurrent Liabilities as of December 31, 2015 .

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVE INSTRUMENTS	DERIVATIVE INSTRUMENTS: Certain SJI subsidiaries are involved in buying, selling, transporting and storing natural gas and buying and selling retail electricity for their own accounts as well as managing these activities for third parties. These subsidiaries are subject to market risk on expected future purchases and sales due to commodity price fluctuations. The Company uses a variety of derivative instruments to limit this exposure to market risk in accordance with strict corporate guidelines. These derivative instruments include forward contracts, swap agreements, options contracts and futures contracts. As of December 31, 2015 , the Company had outstanding derivative contracts intended to limit the exposure to market risk on 82.1 MMdts of expected future purchases of natural gas, 70.1 MMdts of expected future sales of natural gas, 3.2 MMMWh of expected future purchases of electricity and 3.0 MMMWh of expected future sales of electricity. In addition to these derivative contracts, the Company has basis and index related purchase and sales contracts totaling 179.0 MMdts. These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives — Energy Related Assets or Derivatives — Energy Related Liabilities on the consolidated balance sheets. The net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility. As part of its gas purchasing strategy, SJG uses financial contracts through SJRG to limit exposure to forward price risk. The costs or benefits of these short-term contracts are recoverable through SJG's BGSS clause, subject to BPU approval. The retail gas operations of SJE transact commodities on a physical basis and typically does not directly enter into positions that financially settle. SJRG performs this risk management function for SJE and enters into the types of financial transactions noted above. The retail electric operations of SJE use forward physical and financial contracts to mitigate commodity price risk on fixed price electric contracts. Management takes an active role in the risk management process and has developed policies and procedures that require specific administrative and business functions to assist in identifying, assessing and controlling various risks. Management reviews any open positions in accordance with strict policies to limit exposure to market risk. The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, some of which have been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the consolidated balance sheets. Hedge accounting has been discontinued for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously recorded in Accumulated Other Comprehensive Loss (AOCL) on the consolidated balance sheets, are being recorded into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026. As of December 31, 2015 , SJI's active interest rate swaps were as follows: Notional Amount Fixed Interest Rate Start Date Maturity Type of Debt Obligor $ 14,500,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 500,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 330,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 7,100,000 4.895% 2/1/2006 2/1/2016 (A) Taxable Marina $ 12,500,000 3.430% 12/1/2006 2/1/2036 Tax-exempt SJG $ 12,500,000 3.430% 12/1/2006 2/1/2036 Tax-exempt SJG (A) The Company currently does not have any plans to renew this interest rate swap. The unrealized gains and losses on interest rate derivatives that are not designated as cash flow hedges are included in Interest Charges. However, for selected interest rate derivatives at SJG, management believes that, subject to BPU approval, the market value upon termination can be recovered in rates and, therefore, these unrealized losses have been included in Other Regulatory Assets in the consolidated balance sheets. The fair values of all derivative instruments, as reflected in the consolidated balance sheets as of December 31, are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP 2015 2014 Assets Liabilities Assets Liabilities Energy-related commodity contracts: Derivatives – Energy Related – Current 83,093 90,708 $ 85,368 $ 109,744 Derivatives – Energy Related – Non-Current 16,238 21,697 13,905 19,926 Interest rate contracts: Derivatives - Other — 10,943 — 10,732 Total derivatives not designated as hedging instruments under GAAP 99,331 123,348 99,273 140,402 Total Derivatives $ 99,331 $ 123,348 $ 99,273 $ 140,402 The Company enters into derivative contracts with counterparties, some of which are subject to master netting arrangements, which allow net settlements under certain conditions. The Company presents derivatives at gross fair values on the consolidated balance sheets. As of December 31, 2015 and 2014 , information related to these offsetting arrangements were as follows (in thousands): As of December 31, 2015 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets 99,331 — $ 99,331 (35,491 ) (A) — $ 63,840 Derivatives - Energy Related Liabilities (112,405 ) — $ (112,405 ) 35,491 (B) 23,045 $ (53,869 ) Derivatives - Other (10,943 ) — $ (10,943 ) — — $ (10,943 ) As of December 31, 2014 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets 99,273 — $ 99,273 (39,747 ) (A) — $ 59,526 Derivatives - Energy Related Liabilities (129,670 ) — $ (129,670 ) 39,747 (B) 53,897 $ (36,026 ) Derivatives - Other (10,732 ) — $ (10,732 ) — — $ (10,732 ) (A) The balances at December 31, 2015 and 2014 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at December 31, 2015 and 2014 were related to derivative assets which can be net settled against derivative liabilities. The effect of derivative instruments on the statements of consolidated income and comprehensive income for the year ended December 31 is as follows (in thousands): Derivatives in Cash Flow Hedging Relationships 2015 2014 2013 Interest Rate Contracts: Losses recognized in AOCL on effective portion $ — $ — $ — Losses reclassified from AOCL into income (a) $ (551 ) $ (419 ) $ (448 ) Losses recognized in income on ineffective portion (a) — — — (a) Included in Interest Charges Derivatives Not Designated as Hedging Instruments under GAAP 2015 2014 2013 Gains (losses) on energy-related commodity contracts (a) $ 8,401 $ (6,592 ) $ (25,823 ) Gains (losses) on interest rate contracts (b) 96 (467 ) 2,760 Total $ 8,497 $ (7,059 ) $ (23,063 ) (a) Included in Operating Revenues - Nonutility (b) Included in Interest Charges Net realized (losses) gains associated with SJG’s energy-related financial commodity contracts of $(9.1) million , $1.7 million and $(0.4) million for the years ended 2015 , 2014 and 2013 , 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 and there is no impact on earnings. Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on December 31, 2015 , is $48.7 million . If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2015 , the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $45.0 million after offsetting asset positions with the same counterparties under master netting arrangements.

FAIR VALUE OF FINANCIAL ASSETS

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	12 Months Ended
	Dec. 31, 2015
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, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 14,810 $ 2,925 $ 11,885 $ — Derivatives – Energy Related Assets (B) 99,331 16,006 24,730 58,595 $ 114,141 $ 18,931 $ 36,615 $ 58,595 Liabilities Derivatives – Energy Related Liabilities (B) $ 112,405 $ 42,170 $ 11,008 $ 59,227 Derivatives – Other (C) 10,943 — 10,943 — $ 123,348 $ 42,170 $ 21,951 $ 59,227 As of December 31, 2014 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 8,922 $ 5,952 $ 2,970 $ — Derivatives – Energy Related Assets (B) 99,273 21,675 43,093 34,505 $ 108,195 $ 27,627 $ 46,063 $ 34,505 Liabilities Derivatives – Energy Related Liabilities (B) $ 129,670 $ 49,009 $ 40,548 $ 40,113 Derivatives – Other (C) 10,732 — 10,732 — $ 140,402 $ 49,009 $ 51,280 $ 40,113 (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 forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. (C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands, except for ranges): Type Fair Value at December 31, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $ 29,459 $ 31,733 Discounted Cash Flow Forward price (per dt) $(0.77) - $10.00 [$(2.15)] (A) Forward Contract - Electric $ 29,136 $ 27,494 Discounted Cash Flow Fixed electric load profile (on-peak) 8.47% - 100.00% [56.20%] (B) Fixed electric load profile (off-peak) 0.00% - 91.53% [43.80%] (B) Type Fair Value at December 31, 2014 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $ 26,485 $ 33,882 Discounted Cash Flow Forward price (per dt) $(2.04) - $7.83 [$(0.30)] (A) Forward Contract - Electric $ 8,020 $ 6,231 Discounted Cash Flow Fixed electric load profile (on-peak) 8.06% - 100.00% [55.97%] (B) Fixed electric load profile (off-peak) 0.00% - 91.94% [44.03%] (B) (A) Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas. (B) Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak. The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 2015 , using significant unobservable inputs (Level 3), are as follows (in thousands): Year Ended December 31, 2015 Balance at January 1, 2015 $ (5,608 ) Other changes in fair value from continuing and new contracts, net (5,069 ) Transfers in to/(out of) of Level 3 (A) 7,402 Settlements 2,643 Balance at December 31, 2015 $ (632 ) Year Ended December 31, 2014 Balance at January 1, 2014 $ 8,095 Other changes in fair value from continuing and new contracts, net (17,153 ) Settlements 3,450 Balance at December 31, 2014 $ (5,608 ) (A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the year ended December 31, 2015, $7.4 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data, which is assessed quarterly by management. Total losses for 2015 included in earnings for the year ended December 31, 2015 that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of December 31, 2015 , are $5.1 million . These losses are included in Operating Revenues-Nonutility on the statements of consolidated income.

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL)	ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL): The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2015 (in thousands): Postretirement Liability Adjustment Unrealized Gain (Loss) on Derivatives-Other Unrealized Gain (Loss) on Available-for-Sale Securities Other Comprehensive Income (Loss) of Affiliated Companies Total Balance at January 1, 2015 (a) $ (27,663 ) $ (2,450 ) $ (75 ) $ (70 ) $ (30,258 ) Other comprehensive income before reclassifications 1,427 — (76 ) — 1,351 Amounts reclassified from AOCL (b) 4,091 321 23 (27 ) 4,408 Net current period other comprehensive income 5,518 321 (53 ) (27 ) 5,759 Balance at December 31, 2015 (a) $ (22,145 ) $ (2,129 ) $ (128 ) $ (97 ) $ (24,499 ) (a) Determined using a combined average statutory tax rate of 40% . (b) See table below. The following table provides details about reclassifications out of AOCL for the year ended December 31, 2015 (in thousands): Amounts Reclassified from AOCL Affected Line Item in the Condensed Consolidated Statements of Income For the Year Ended December 31, 2015 Actuarial Loss on Postretirement Benefits $ 6,763 Operating Expenses: Operations Income Taxes (2,672 ) Income Taxes (a) $ 4,091 Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 551 Interest Charges Income Taxes (230 ) Income Taxes (a) $ 321 Unrealized Loss on Available-for-Sale Securities $ 37 Other Income Income Taxes (14 ) Income Taxes (a) $ 23 Income of Affiliated Companies $ (45 ) Equity in Loss of Affiliated Companies Income Taxes 18 Income Taxes (a) $ (27 ) Losses from reclassifications for the period net of tax $ 4,408 (a) Determined using a combined average statutory tax rate of 40% .

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2015
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS: In January 2016, the Company paid $12.7 million to a third party to retire outstanding debt for ACB (see Note 14). In January 2016, Energenic and certain subsidiaries reached a multi-party settlement with the bondholders of the central energy center constructed to serve a hotel, casino and entertainment complex in Atlantic City, NJ (See Note 7). This agreement resolves all outstanding litigation and transfers ownership of the bondholders’ collateral to the owners of the entertainment complex. The Company’s share of this settlement was $7.5 million which was accrued by Energenic as of December 31, 2015. Management of Energenic is currently in active settlement discussions and believes that this amount is recoverable from its insurance carrier and external legal advisors.

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	Quarterly Financial Data (Unaudited) (Summarized quarterly results of SJI's operations, in thousands except for per share amounts) 2015 Quarter Ended 2014 Quarter Ended March 31 June 30 Sept. 30 Dec. 31 March 31 June 30 Sept. 30 Dec. 31 Operating Revenues $ 382,952 $ 177,710 $ 141,062 $ 257,844 $ 350,201 $ 133,271 $ 122,427 $ 281,097 Expenses: Cost of Sales - (Excluding depreciation) 241,707 90,945 99,124 127,566 228,138 78,947 76,073 153,794 Operations and Maintenance Including Fixed Charges 71,279 62,634 63,867 71,148 64,684 56,174 56,039 69,384 Income Taxes 16,613 (3,279 ) (10,968 ) (1,006 ) 11,869 (9,510 ) (8,325 ) 10,415 Energy and Other Taxes 2,196 1,265 1,231 1,334 1,953 1,241 1,196 1,330 Total Expenses 331,795 151,565 153,254 199,042 306,644 126,852 124,983 234,923 Other Income and Expense 2,696 (12,804 ) (340 ) (7,854 ) 4,654 3,282 (1,720 ) (2,182 ) Income (Loss) from Continuing Operations 53,853 13,341 (12,532 ) 50,948 48,211 9,701 (4,276 ) 43,992 Loss from Discontinued Operations - (Net of tax benefit) (276 ) (74 ) (91 ) (62 ) (313 ) (80 ) (120 ) (69 ) Net Income (Loss) $ 53,577 $ 13,267 $ (12,623 ) $ 50,886 $ 47,898 $ 9,621 $ (4,396 ) $ 43,923 Basic Earnings Per Common Share: Continuing Operations $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 $ 0.74 $ 0.15 $ (0.07 ) $ 0.66 Discontinued Operations — — — — — — — — Basic Earnings Per Common Share $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 $ 0.74 $ 0.15 $ (0.07 ) $ 0.66 Average Shares of Common Stock Outstanding - Basic 68,397 68,467 68,607 69,460 65,530 65,926 66,332 67,304 Diluted Earnings Per Common Share: Continuing Operations $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 $ 0.74 $ 0.15 $ (0.07 ) $ 0.65 Discontinued Operations — — — — — — — — Diluted Earnings Per Common Share $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 $ 0.74 $ 0.15 $ (0.07 ) $ 0.65 Average Shares of Common Stock Outstanding - Diluted 68,618 68,653 68,607 69,646 65,684 66,074 66,332 67,454 The sum of the quarters for 2015 and 2014 do not equal the year's total due to rounding. All share and per share amounts were adjusted for all periods presented for the 2 -for-1 stock split, effected in the form of a stock dividend, effective on May 8, 2015. See Note 1 to the consolidated financial statements. NOTE: Because of the seasonal nature of the business and the volatility from energy-related derivatives, statements for the 3-month periods are not indicative of the results for a full year.

Schedule I

Schedule I	12 Months Ended
	Dec. 31, 2015
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Schedule I	SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED STATEMENTS OF INCOME (In Thousands) 2015 2014 2013 Management Service Fee Revenues $ 20,990 $ 21,118 $ 16,269 Operating Expenses: Operations 17,979 18,183 14,979 Depreciation 406 439 260 Energy and Other Taxes 806 813 465 Total Operating Expenses 19,191 19,435 15,704 Operating Income 1,799 1,683 565 Other Income: Equity in Earnings of Subsidiaries 105,610 97,628 82,389 Other 10,145 7,283 5,459 Total Other Income 115,755 104,911 87,848 Interest Charges 11,822 8,803 6,004 Income Taxes 122 163 20 Income from Continuing Operations 105,610 97,628 82,389 Equity in Undistributed Earnings of Discontinued Operations (503 ) (582 ) (796 ) Net Income $ 105,107 $ 97,046 $ 81,593 SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (In Thousands) 2015 2014 2013 Net Income $ 105,107 $ 97,046 $ 81,593 Other Comprehensive (Loss) Income - Net of Tax* Postretirement Liability Adjustment 5,518 (9,160 ) 4,934 Unrealized (Loss) Gain on Available-for-Sale Securities (53 ) (472 ) 103 Unrealized Gain (Loss) on Derivatives 294 134 5,308 Total Other Comprehensive (Loss) Income - Net of Tax* 5,759 (9,498 ) 10,345 Comprehensive Income $ 110,866 $ 87,548 $ 91,938 * For 2015 and 2014, determined using a combined average statutory tax rate of 40% . For 2013, determined using a combined statutory tax rate of 41% SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED STATEMENTS OF RETAINED EARNINGS (In Thousands) 2015 2014 2013 Retained Earnings - Beginning $ 439,218 $ 406,041 $ 382,127 Net Income 105,107 97,046 81,593 544,325 503,087 463,720 Dividends Declared - Common Stock (70,158 ) (63,869 ) (57,679 ) Retained Earnings - Ending $ 474,167 $ 439,218 $ 406,041 SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED STATEMENTS OF CASH FLOWS FOR THE TWELVE MONTHS ENDED DECEMBER 31, (In Thousands) 2015 2014 2013 CASH PROVIDED BY OPERATING ACTIVITIES $ 38,593 $ 22,244 $ 1,316 CASH FLOWS FROM INVESTING ACTIVITIES: Net Advances to Associated Companies (118,802 ) (104,979 ) (68,900 ) Capital Expenditures (150 ) (1,610 ) (360 ) Proceeds from Sale of Property, Plant & Equipment — 27 6 Purchase of Company Owned Life Insurance (2,328 ) (1,250 ) (5,149 ) Investment in Affiliate — (25,000 ) (25,000 ) Net Cash Used In Investing Activities (121,280 ) (132,812 ) (99,403 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from Issuance of Long Term Debt 50,000 240,000 — Principal Repayments of Long Term Debt (114,000 ) — — Payments for Issuance of Long Term Debt (55 ) (1,558 ) — Net Borrowings from (Repayments of) Lines of Credits 153,000 (144,100 ) 101,600 Dividends on Common Stock (70,158 ) (63,869 ) (57,679 ) Proceeds from Sale of Common Stock 63,192 80,680 54,028 Net Cash Provided by Financing Activities 81,979 111,153 97,949 NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS (708 ) 585 (138 ) CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 2,416 1,831 1,969 CASH AND CASH EQUIVALENTS AT END OF YEAR $ 1,708 $ 2,416 $ 1,831 SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC. CONDENSED BALANCE SHEETS (In Thousands) 2015 2014 Assets Property Plant and Equipment: Nonutility Property, Plant and Equipment, at cost $ 2,468 $ 3,521 Accumulated Depreciation (1,768 ) (1,370 ) Property, Plant and Equipment - Net 700 2,151 Investments: Investments in Subsidiaries 1,051,675 983,721 Available-for-Sale Securities 3,860 28 Total Investments 1,055,535 983,749 Current Assets: Cash and Cash Equivalents 1,708 2,416 Receivable from Associated Companies 582,406 463,756 Accounts Receivable 49 35 Other 2,859 747 Total Current Assets 587,022 466,954 Other Noncurrent Assets 39,503 44,887 Total Assets $ 1,682,760 $ 1,497,741 Capitalization and Liabilities Equity: Common Stock SJI Par Value $1.25 a share Authorized - 120,000,000 shares Outstanding - 70,965,622 (2015) and 68,334,860 (2014) 88,707 $ 42,709 Premium on Common Stock 499,460 480,928 Treasury Stock (at par) (296 ) (165 ) Accumulated Other Comprehensive Loss (24,499 ) (30,258 ) Retained Earnings 474,167 439,218 Total Equity 1,037,539 932,432 Long-Term Debt 341,000 291,000 Current Liabilities: Notes Payable - Banks 297,300 144,300 Current Portion of Long-Term Debt — 114,000 Payable to Associated Companies 262 413 Accounts Payable 425 400 Other Current Liabilities 3,579 5,062 Total Current Liabilities 301,566 264,175 Other Noncurrent Liabilities 2,655 10,134 Total Capitalization and Liabilities $ 1,682,760 $ 1,497,741 Notes to Condensed Financial Statements 1. BASIS OF PRESENTATION: Pursuant to rules and regulations of the SEC, the unconsolidated condensed financial statements of SJI do not reflect all of the information and notes normally included with financial statements prepared in accordance with GAAP in the United States. Therefore, these condensed financial statements should be read in conjunction with the consolidated financial statements and related notes included under Item 8 in this Form 10-K. Dividends received from subsidiaries amounted to $40.8 million and $18.2 million in 2015 and 2014, respectively. No dividends were received from subsidiaries in 2013.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2015
Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS (In Thousands) Col. A Col. B Col. C Col. D Col. E Additions Classification Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts - Describe (a) Deductions - Describe (b) Balance at End of Period Provision for Uncollectible Accounts for the Year Ended December 31, 2015 $ 7,910 $ 14,730 $ (79 ) $ 12,309 $ 10,252 Provision for Uncollectible Accounts for the Year Ended December 31, 2014 $ 5,854 $ 9,519 $ (102 ) $ 7,361 $ 7,910 Provision for Uncollectible Accounts for the Year Ended December 31, 2013 $ 5,924 $ 4,245 $ (41 ) $ 4,274 $ 5,854 (a) Recoveries of accounts previously written off and minor adjustments. (b) Uncollectible accounts written off.

SUMMARY OF SIGNIFICANT ACCOUN31

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
GENERAL	GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy-related products and services primarily through the following wholly-owned subsidiaries: ▪ South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey. ▪ South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers. ▪ South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets along with fuel management services on a wholesale basis in the mid-Atlantic, Appalachian and southern states. ▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. ▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. The following entities are wholly-owned subsidiaries of Marina as of December 31, 2015 (see Note 3): • ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey. • AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties located in New Jersey. • MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey. ▪ South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. • SJI Midstream, LLC was formed in 2014 to invest in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.
BASIS OF PRESENTATION	BASIS OF PRESENTATION - The consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI's financial position, operating results and cash flows at the dates and for the periods presented.
RECLASSIFICATIONS	Certain reclassifications have been made to the prior period's regulatory liabilities disclosure to conform to the current period presentation. The societal benefit costs payable previously included in "Other Regulatory Liabilities" were reclassified to the line item "Societal Benefit Costs Payable" in the regulatory liabilities table disclosed in Note 11. Certain reclassifications have been made to the prior period's deferred tax asset/liability disclosure to conform to the current period presentation. The breakout of current and noncurrent assets/liabilities previously disclosed in Note 4 was reclassified to separate deferred tax assets and deferred tax liabilities as disclosed in Note 4.
EQUITY INVESTMENTS	EQUITY INVESTMENTS - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. SJI, through wholly owned subsidiaries, holds significant variable interests in several companies but is not the primary beneficiary. Consequently, these investments are accounted for under the equity method. In the event that losses and/or distributions from these equity method investments exceed the carrying value, and the Company is obligated to provide additional financial support, the excess will be recorded as either a current or non-current liability on the consolidated balance sheets. We include the operations of these affiliated companies on a pre-tax basis in the statements of consolidated income under Equity in (Loss) Earnings of Affiliated Companies (See Note 3). An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary.
ESTIMATES AND ASSUMPTIONS	ESTIMATES AND ASSUMPTIONS - We prepare our consolidated financial statements to conform with accounting principles generally accepted in the United States of America (GAAP). Management makes estimates and assumptions that affect the amounts reported in the consolidated financial statements and related disclosures. Therefore, actual results could differ from those estimates. Significant estimates include amounts related to regulatory accounting, energy derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition.
REGULATION	REGULATION - SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 10 for a detailed discussion of SJG's rate structure and regulatory actions. SJG maintains its accounts according to the BPU's prescribed Uniform System of Accounts. SJG follows the accounting for regulated enterprises prescribed by Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980 -”Regulated Operations.” In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 11 for a detailed discussion of regulatory assets and liabilities.
OPERATING REVENUES	OPERATING REVENUES - Gas and electric revenues are recognized in the period the commodity is delivered to customers. For SJG and SJE retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas and electricity delivered from the date of the last meter reading to the end of the month. SJRG's gas revenues are recognized in the period the commodity is delivered. Realized and unrealized gains and losses on energy-related derivative instruments are also recognized in operating revenues for SJRG. See further discussion under Derivative Instruments. SJRG presents revenues and expenses related to its energy trading activities on a net basis in operating revenues. This net presentation has no effect on operating income or net income. We recognize revenues related to SJESP appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenue related to services provided on a time and materials basis is recognized on a monthly basis as the services are provided. Marina recognizes revenue on a monthly basis as services are provided, as lease income is earned, and for on-site energy production that is delivered to its customers.
REVENUE AND THROUGHPUT-BASED TAXES	REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses.
ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLETIBLE ACCOUNTS	ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLECTIBLE ACCOUNTS - Accounts receivable are carried at the amount owed by customers. A provision for uncollectible accounts is established based on our collection experience and an assessment of the collectibility of specific accounts.
PROPERTY, PLANT AND EQUIPMENT	PROPERTY, PLANT AND EQUIPMENT - For regulatory purposes, utility plant is stated at original cost, which may be different than SJG's cost if the assets were acquired from another regulated entity. Nonutility plant is stated at cost. The cost of adding, replacing and renewing property is charged to the appropriate plant account.
ASSET RETIREMENT OBLIGATIONS	ASSET RETIREMENT OBLIGATIONS - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations the Company has to cut and cap gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.
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 2015 , 2.2% in 2014 , and 2.3% in 2013 . The actual composite rate may differ from the approved rate as the asset mix changes over time. Except for retirements outside of the normal course of business, accumulated depreciation is charged with the cost of depreciable utility property retired, less salvage. Nonutility property depreciation is computed on a straight-line basis over the estimated useful lives of the property, ranging up to 50 years. Gain or loss on the disposition of nonutility property is recognized in operating income.
CAPITALIZED INTEREST	CAPITALIZED INTEREST - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in SJG's last base rate proceeding. For SJG's accelerated infrastructure programs, SJG capitalizes interest on construction at a rate prescribed by the programs (see Note 10). Marina, SJRG and SJE capitalize interest on capital projects in progress based on the actual cost of borrowed funds. SJG's amounts are included in Utility Plant and Marina's amounts are included in Nonutility Property and Equipment on the consolidated balance sheets. Interest Charges are presented net of capitalized interest on the statements of consolidated income.
IMPAIRMENT OF LONG-LIVED ASSETS	IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable.
DERIVATIVE INSTRUMENTS	DERIVATIVE INSTRUMENTS - SJI accounts for derivative instruments in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.” We record all derivatives, whether designated in hedging relationships or not, on the consolidated balance sheets at fair value unless the derivative contracts qualify for the normal purchase and sale exemption. In general, if the derivative is designated as a fair value hedge, we recognize the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk in earnings. We currently have no fair value hedges. If the derivative is designated as a cash flow hedge, we record the effective portion of the hedge in Accumulated Other Comprehensive Loss and recognize it in the income statement when the hedged item affects earnings. We recognize ineffective portions of the cash flow hedges immediately in earnings. We currently have no cash flow hedges. We formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. Due to the application of regulatory accounting principles under FASB ASC Topic 980, gains and losses on derivatives related to SJG's gas purchases are recorded through the Basic Gas Supply Service (BGSS) clause. Initially and on an ongoing basis, we assess whether derivatives designated as hedges are highly effective in offsetting changes in cash flows or fair values of the hedged items. We discontinue hedge accounting prospectively if we decide to discontinue the hedging relationship; determine that the anticipated transaction is no longer likely to occur; or determine that a derivative is no longer highly effective as a hedge. In the event that hedge accounting is discontinued, we will continue to carry the derivative on the balance sheet at its current fair value and recognize subsequent changes in fair value in current period earnings. Unrealized gains and losses on the discontinued hedges that were previously included in Accumulated Other Comprehensive Loss will be reclassified into earnings when the forecasted transaction occurs, or when it is probable that it will not occur. Hedge accounting has been discontinued for all remaining derivatives that were designated as hedging instruments.
GAS EXPLORATION AND DEVELOPMENT	GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred.
TREASURY STOCK	TREASURY STOCK – SJI uses the par value method of accounting for treasury stock.
INCOME TAXES	INCOME TAXES - Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with FASB ASC Topic 740 - “Income Taxes” (See Note 4). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow through method.
CASH AND CASH EQUIVALENTS	CASH AND CASH EQUIVALENTS - For purposes of reporting cash flows, highly liquid investments with original maturities of three months or less are considered cash equivalents.
IDENTIFIABLE INTANGIBLE ASSETS	IDENTIFIABLE INTANGIBLE ASSETS - Identifiable intangible assets were acquired as part of the acquisition of Energenic projects as discussed in Note 3. The primary identifiable intangible assets of the Company are customer relationships. The Company determines the useful lives of identifiable intangible assets after considering the specific facts and circumstances related to each intangible asset. Considerations may include the contractual term of any agreement related to the asset, the historical performance of the asset, the Company's long-term strategy for using the asset, any laws or other local regulations which could impact the useful life of the asset, and other economic factors, including competition and specific market conditions. Intangible assets that are deemed to have definite lives (finite-lived intangible assets) are amortized, primarily on a straight-line basis, over their useful lives, generally ranging from 2 to 20 years.
GOODWILL	GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects as discussed in Note 3. Goodwill represents the excess of the consideration paid over the fair value of identifiable net assets acquired. Goodwill is not amortized, but instead is subject to impairment testing on an annual basis, and between annual tests whenever events or changes in circumstances indicate that the fair value of a reporting unit may be below its carrying amount.
NEW ACCOUNTING PRONOUNCEMENTS	NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2015 or 2014 had, or is expected to have, a material impact on the consolidated financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition , and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption. In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis , which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015, with early adoption permitted. The Company does not expect this standard to have a significant impact on its consolidated financial statements upon adoption. In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs . This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. The adoption of this guidance will not have an impact on the Company's financial statement results; however, balance sheet presentations will be modified to conform to this guidance. 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 is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. The Company does not expect this standard to have a significant impact on its consolidated financial statements upon adoption. 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 August 2015, the FASB issued ASU 2015-13, Derivatives and Hedging (Topic 815): Application of the Normal Purchases and Normal Sales Scope Exception to Certain Electricity Contracts within Nodal Energy Markets . This ASU clarifies that for a contract involving the purchase or sale of electricity on a forward basis, companies have the option to elect the normal purchases and normal sales scope exception. Since such contracts meet the physical delivery criterion when the delivery location is within a nodal energy market (i.e., an interconnected electricity grid operated by an independent system operator with established price points at each node or hub location), the ASU notes that it does not constitute net settlement and, consequently, does not cause such a contract to fail to meet the physical delivery criterion. The standard is effective immediately and should be applied prospectively to qualifying contracts existing on August 10, 2015, the date the ASU was issued. The adoption of this standard did not have an impact on the Company's financial statement results. In August 2015, the FASB issued ASU 2015-15, Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements . This ASU states that, given the absence of authoritative guidance for debt issuance costs related to line-of-credit arrangements within ASU 2015-03 (defined above), the SEC staff would not object to an entity deferring and presenting such costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of credit arrangement. The adoption of this standard did not have an impact on the Company's financial statement results. In November 2015, the FASB issued ASU 2015-17, Balance Sheet Classification of Deferred Taxes , which simplifies the presentation of deferred taxes by requiring that deferred tax assets and liabilities be presented as noncurrent on the balance sheet. ASU 2015-17 is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2016. Early adoption is permitted for financial statements that have not been previously issued. ASU 2015-17 may be applied either prospectively to all deferred tax liabilities and assets or retrospectively to all periods presented. The Company adopted this guidance, prospectively, as of December 31, 2015.
FAIR VALUE	GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. The levels of the hierarchy are described below: • Level 1: Observable inputs, such as quoted prices in active markets for identical assets or liabilities. • Level 2: Inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly; these include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active. • Level 3: Unobservable inputs that reflect the reporting entity’s own assumptions. Assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of financial assets and financial liabilities and their placement within the fair value hierarchy. (A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy. (B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. (C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

SUMMARY OF SIGNIFICANT ACCOUN32

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Asset retirement obligation activity	ARO activity was as follows (in thousands): 2015 2014 AROs as of January 1, $ 42,502 $ 41,687 Accretion 1,675 1,612 Additions 802 664 Settlements (1,110 ) (1,461 ) Revisions in Estimated Cash Flows (A) 14,074 — ARO's as of December 31, $ 57,943 $ 42,502 (A) The revision in estimated cash flows reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.

STOCK-BASED COMPENSATION PLAN (

STOCK-BASED COMPENSATION PLAN (Tables)	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of the nonvested restricted stock awards outstanding and the assumptions used to estimate the fair value of the awards	The following table summarizes the nonvested restricted stock awards outstanding at December 31, 2015 , and the assumptions used to estimate the fair value of the awards: Grants Shares Outstanding Fair Value Per Share Expected Volatility Risk-Free Interest Rate Officers & Key Employees - 2014 - TSR 51,349 $ 21.31 20.0 % 0.80 % 2014 - EPS 51,349 $ 27.22 N/A N/A 2015 - TSR 34,574 $ 26.31 16.0 % 1.10 % 2015 - EPS, ROE, Time 88,919 $ 29.47 N/A N/A Directors - 2015 26,338 $ 29.21 N/A N/A
Summary of the total stock-based compensation cost for the period	The following table summarizes the total stock-based compensation cost for the years ended December 31 (in thousands): 2015 2014 2013 Officers & Key Employees $ 1,128 $ 1,260 $ 2,236 Directors 769 633 765 Total Cost 1,897 1,893 3,001 Capitalized (216 ) (147 ) (237 ) Net Expense $ 1,681 $ 1,746 $ 2,764
Summary of information regarding restricted stock award activity during the period excluding accrued dividend equivalents	The following table summarizes information regarding restricted stock award activity during 2015 , excluding accrued dividend equivalents: Officers & Other Key Employees Directors Weighted Average Fair Value Nonvested Shares Outstanding, January 1, 2015 223,876 23,220 $ 24.40 Granted 158,929 26,338 $ 28.67 Vested* (91,244 ) (23,220 ) $ 24.57 Cancelled/Forfeited** (65,370 ) — $ 26.56 Nonvested Shares Outstanding, December 31, 2015 226,191 26,338 $ 26.89 *Based on performance information available at the filing of this Report, management does not expect to award shares associated with the 2013 grants to officers and other key employees in 2016. ** Represents shares forfeited as a result of retirements prior to the satisfaction of service conditions.

AFFILIATIONS AND DISCONTINUED34

AFFILIATIONS AND DISCONTINUED OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Schedule of the fair value of the assets acquired and the liabilities assumed	The following table summarizes the preliminary purchase price allocation and reflects 100% of the fair values of the assets acquired and the liabilities assumed by the Company in connection with the Transaction. The Company is still awaiting final valuation reports supporting the allocation of the purchase price to certain identifiable intangibles. Total consideration for the step acquisition of the remaining interest in the Marina Projects was $46.1 million , which represents the fair value of the Company’s interest in the Partner Projects exchanged ( $31.5 million ) as well as the existing value of the Marina Projects immediately prior to the exchange ( $14.6 million ) (in thousands): Current assets (excluding inventory) $ 7,804 Inventory 3,154 Note Receivable Received 19,504 Fixed Assets 40,854 Intangible Assets: Identifiable Intangibles 21,553 Goodwill 8,880 Non-Current Assets 1,873 Current Liabilities (8,196 ) Note Payable - Affiliate (16,986 ) Long-Term Debt, including current portion (21,457 ) Capital Lease Payable (10,357 ) Other Non-Current Liabilities (572 ) Fair Value of Consolidated Assets and Liabilities of Acquired Projects $ 46,054
Schedule of equity method investments	The following tables present summarized financial information of the total balances for all Affiliates (of which, on average, SJI has only a 50% equity interest) accounted for under the equity method (in thousands): 2015 2014 Current assets $ 21,914 $ 46,683 Noncurrent assets $ 117,091 $ 478,240 Current liabilities $ 47,797 $ 75,260 Noncurrent liabilities $ 112,438 $ 315,801 As of December 31, 2015, the assets and liabilities of the projects that are now wholly owned by Marina as discussed above are consolidated into the consolidated balance sheets. As such, they are not included in the above table. 2015 2014 2013 Revenues $ 163,479 $ 207,031 $ 178,026 Cost of sales $ 86,452 $ 107,042 $ 91,228 (Loss) Income from continuing operations $ (56,962 ) $ (11,666 ) $ 6,229 Net (Loss) Income $ (56,962 ) $ (11,666 ) $ 6,229

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Schedule of components of income tax expense (benefit) and effective income tax rate reconciliation	Total income taxes applicable to operations differ from the tax that would have resulted by applying the statutory Federal income tax rate to pre-tax income for the following reasons (in thousands): 2015 2014 2013 Tax at Statutory Rate $ 37,440 $ 35,727 $ 22,181 Increase (Decrease) Resulting from: State Income Taxes 3,985 1,960 971 ESOP Dividend (1,298 ) (1,232 ) (1,176 ) Amortization of Investment Tax Credits - Utility (149 ) (211 ) (258 ) AFUDC (1,109 ) (1,481 ) (916 ) Investment and Other Tax Credits (37,503 ) (30,661 ) (38,179 ) Other - Net (6 ) 347 (1,637 ) Income Taxes: Continuing Operations 1,360 4,449 (19,014 ) Discontinued Operations (257 ) (312 ) (426 ) Total Income Tax Expense (Benefit) $ 1,103 $ 4,137 $ (19,440 ) The provision for Income Taxes is comprised of the following (in thousands): 2015 2014 2013 Current: Federal $ — $ (62 ) $ (273 ) State (2,352 ) 3,052 3,066 Total Current (2,352 ) 2,990 2,793 Deferred: Federal (4,622 ) 1,707 (19,978 ) State 8,483 (37 ) (1,571 ) Total Deferred 3,861 1,670 (21,549 ) Investment Tax Credit - Utility (149 ) (211 ) (258 ) Income Taxes: Continuing Operations 1,360 4,449 (19,014 ) Discontinued Operations (257 ) (312 ) (426 ) Total Income Tax Expense (Benefit) $ 1,103 $ 4,137 $ (19,440 )
Schedule of deferred tax assets and liabilities	The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax assets and liabilities at December 31 (in thousands): 2015 2014 Deferred Tax Assets: Net Operating Loss Carryforward $ 195,358 $ 157,174 Investment and Other Tax Credits 200,491 154,805 Derivatives / Unrealized Gain 5,652 12,554 Conservation Incentive Program — 2,027 Deferred State Tax 24,833 21,548 Investment Tax Credit Basis Gross-Up — 77 Pension & Other Post Retirement Benefits 29,998 34,892 Deferred Revenues 4,924 11,647 Provision for Uncollectibles 4,200 6,296 Other 6,448 6,734 Total Deferred Tax Asset $ 471,904 $ 407,754 Deferred Tax Liabilities: Book versus Tax Basis of Property $ 675,521 $ 558,960 Deferred Gas Costs - Net 3,998 22,959 Environmental Remediation 19,207 12,147 Deferred Regulatory Costs 566 6,333 Budget Billing - Customer Accounts 830 1,138 Deferred Pension & Other Post Retirement Benefits 42,216 39,891 Conservation Incentive Program 1,132 — Equity In Loss Of Affiliated Companies 9,111 39,230 Other 15,268 13,868 Total Deferred Tax Liability $ 767,849 $ 694,526 Deferred Tax Liability - Net $ 295,945 $ 286,772 Current Deferred Tax Asset $ — $ (57,748 ) Noncurrent Deferred Tax Liability 295,945 344,520 Deferred Tax Liability - Net $ 295,945 $ 286,772
Summary of operating loss carryforward	As of December 31, 2015 , SJI has the following federal and state net operating loss carryforwards (in thousands): Net Operating Loss Carryforwards Expire in: Federal State 2031 $ 163,880 $ 45,866 2032 43,724 19,356 2033 68,696 34,940 2034 117,325 28,622 2035 133,782 21,685 $ 527,407 $ 150,469
Summary of tax credit carryforwards	As of December 31, 2015 , SJI has the following investment tax credit carryforwards (in thousands): Expire in: Investment Tax Credit Carryforward 2030 $ 11,628 2031 26,613 2032 32,071 2033 46,179 2034 38,727 2035 42,548 $ 197,766
Reconciliation of unrecognized tax benefits	A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands): 2015 2014 2013 Balance at January 1, $ 552 $ 547 $ 503 Increase as a result of tax positions taken in prior years 7 5 44 Decrease due to a lapse in the statute of limitations — — — Settlements — — — Balance at December 31, $ 559 $ 552 $ 547

COMMON STOCK (Tables)

COMMON STOCK (Tables)	12 Months Ended
	Dec. 31, 2015
Common Stock [Abstract]
Common stock shares issued and outstanding	The following shares were issued and outstanding at December 31 (See Note 1): 2015 2014 2013 Beginning of Year 68,334,860 65,430,084 63,306,524 New Issues During Year: Dividend Reinvestment Plan 2,604,424 2,881,556 1,966,834 Stock-Based Compensation Plan 26,338 23,220 156,726 End of Year 70,965,622 68,334,860 65,430,084

SEGMENTS OF BUSINESS (Tables)

SEGMENTS OF BUSINESS (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Segments of Business	Information about SJI’s operations in different reportable operating segments is presented below (in thousands): 2015 2014 2013 Operating Revenues: Gas Utility Operations $ 534,290 $ 501,875 $ 446,480 Energy Group: Wholesale Energy Operations 129,098 77,048 831 Retail Gas and Other Operations 87,198 127,001 107,748 Retail Electric Operations 150,049 123,773 128,932 Subtotal Energy Group 366,345 327,822 237,511 Energy Services: On-Site Energy Production 63,665 56,129 43,551 Appliance Service Operations 11,186 10,518 13,723 Subtotal Energy Services 74,851 66,647 57,274 Corporate & Services 31,156 30,174 31,286 Subtotal 1,006,642 926,518 772,551 Intersegment Sales (47,074 ) (39,522 ) (41,130 ) Total Operating Revenues $ 959,568 $ 886,996 $ 731,421 2015 2014 2013 Operating Income: Gas Utility Operations $ 119,585 $ 113,690 $ 105,822 Energy Group: Wholesale Energy Operations 35,024 9,493 (37,720 ) Retail Gas and Other Operations (3,218 ) 479 278 Retail Electric Operations 1,042 (466 ) (98 ) Subtotal Energy Group 32,848 9,506 (37,540 ) Energy Services: On-Site Energy Production 2,027 2,560 (2,011 ) Appliance Service Operations 468 362 2,995 Subtotal Energy Services 2,495 2,922 984 Corporate and Services 1,966 1,485 370 Total Operating Income $ 156,894 $ 127,603 $ 69,636 Depreciation and Amortization: Gas Utility Operations $ 58,668 $ 52,155 $ 48,261 Energy Group: Wholesale Energy Operations 435 168 206 Retail Gas and Other Operations 161 83 93 Subtotal Energy Group 596 251 299 Energy Services: On-Site Energy Production 30,242 25,020 15,192 Appliance Service Operations 316 269 261 Subtotal Energy Services 30,558 25,289 15,453 Corporate and Services 1,220 816 877 Total Depreciation and Amortization $ 91,042 $ 78,511 $ 64,890 Interest Charges: Gas Utility Operations $ 19,906 $ 17,872 $ 12,550 Energy Group: Wholesale Energy Operations 441 371 417 Retail Gas and Other Operations 185 267 280 Subtotal Energy Group 626 638 697 Energy Services: On-Site Energy Production 8,169 8,723 4,480 Corporate and Services 11,822 8,803 6,004 Subtotal 40,523 36,036 23,731 Intersegment Borrowings (8,901 ) (6,476 ) (4,906 ) Total Interest Charges $ 31,622 $ 29,560 $ 18,825 2015 2014 2013 Income Taxes: Gas Utility Operations $ 36,945 $ 34,895 $ 34,833 Energy Group: Wholesale Energy Operations 14,410 4,822 (15,070 ) Retail Gas and Other Operations (978 ) 787 434 Retail Electric Operations 426 (190 ) (40 ) Subtotal Energy Group 13,858 5,419 (14,676 ) Energy Services: On-Site Energy Production (49,225 ) (36,404 ) (40,755 ) Appliance Service Operations 186 223 1,237 Subtotal Energy Services (49,039 ) (36,181 ) (39,518 ) Corporate and Services (404 ) 316 347 Total Income Taxes $ 1,360 $ 4,449 $ (19,014 ) Property Additions: Gas Utility Operations $ 218,260 $ 201,737 $ 173,099 Energy Group: Wholesale Energy Operations 382 18 50 Retail Gas and Other Operations 2,053 1,421 702 Subtotal Energy Group 2,435 1,439 752 Energy Services: On-Site Energy Production (1) 139,018 132,214 151,592 Appliance Service Operations 379 84 — Subtotal Energy Services 139,397 132,298 151,592 Corporate and Services 1,902 3,995 3,061 Total Property Additions $ 361,994 $ 339,469 $ 328,504 (1) The property additions for On-Site Energy Production do not include the approximately $40.9 million of Property, Plant and Equipment obtained through the acquisition of eight Energenic projects as discussed in Note 3. 2015 2014 Identifiable Assets: Gas Utility Operations $ 2,288,204 $ 2,185,672 Energy Group: Wholesale Energy Operations 231,660 366,119 Retail Gas and Other Operations 55,111 53,073 Retail Electric Operations 55,528 23,682 Subtotal Energy Group 342,299 442,874 Energy Services: On-Site Energy Production 791,236 675,937 Appliance Service Operations 4,885 3,105 Subtotal Energy Services 796,121 679,042 Discontinued Operations 1,545 1,758 Corporate and Services 653,659 527,691 Intersegment Assets (600,928 ) (487,612 ) Total Identifiable Assets $ 3,480,900 $ 3,349,425

LEASES (Tables)

LEASES (Tables)	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Schedule of Future Minimum Rental Payments For Operating Lease	Minimum future rentals to be received on this operating lease of property and equipment as of December 31, 2015 for each of the next five years and in the aggregate are (in thousands): Year ended December 31, 2016 $ 5,396 2017 5,396 2018 5,396 2019 5,396 2020 5,396 Thereafter 34,626 Total minimum future rentals 61,606
Schedule of Future Minimum Lease Payments for Capital Leases	Minimum future rentals to be paid on this capital lease of property and equipment as of December 31, 2015 for each of the next five years and in the aggregate are (in thousands): Year ended December 31, 2016 $ 1,282 2017 1,282 2018 1,282 2019 1,282 2020 1,282 Thereafter 8,657 Total minimum future rentals 15,067 Less: Interest portion (4,710 ) Present value of future minimum lease payments $ 10,357

REGULATORY ASSETS & REGULATOR39

REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2015
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets	Regulatory Assets consisted of the following items (in thousands): December 31, 2015 December 31, 2014 Environmental Remediation Costs: Expended - Net $ 42,032 $ 29,540 Liability for Future Expenditures 123,194 124,308 Deferred Asset Retirement Obligation Costs 42,430 31,584 Deferred Pension and Other Postretirement Benefit Costs 79,779 99,040 Deferred Gas Costs - Net 2,701 32,202 Conservation Incentive Program Receivable 2,624 — Societal Benefit Costs Receivable — 385 Deferred Interest Rate Contracts 7,631 7,325 Energy Efficiency Tracker 496 11,247 Pipeline Supplier Service Charges 3,776 5,441 Pipeline Integrity Cost 4,596 3,431 AFUDC - Equity Related Deferrals 11,423 10,781 Other Regulatory Assets 2,752 1,876 Total Regulatory Assets $ 323,434 $ 357,160
Schedule of Regulatory Liabilities	Regulatory Liabilities consisted of the following items (in thousands): December 31, 2015 December 31, 2014 Excess Plant Removal Costs $ 32,644 $ 35,940 Societal Benefit Costs Payable 10,197 1,025 Conservation Incentive Program - Payable — 4,700 Other Regulatory Liabilities — 234 Total Regulatory Liabilities $ 42,841 $ 41,899

PENSION AND OTHER POSTRETIREM40

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	12 Months Ended
	Dec. 31, 2015
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of Net 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 2015 2014 2013 Service Cost $ 5,337 $ 4,510 $ 5,421 Interest Cost 11,168 10,735 9,439 Expected Return on Plan Assets (14,789 ) (13,491 ) (11,914 ) Amortizations: Prior Service Cost 212 175 251 Actuarial Loss 10,608 5,716 9,006 Net Periodic Benefit Cost 12,536 7,645 12,203 Capitalized Benefit Costs (4,805 ) (3,047 ) (5,002 ) Deferred Benefit Costs (1,007 ) — — Total Net Periodic Benefit Expense $ 6,724 $ 4,598 $ 7,201 Other Postretirement Benefits 2015 2014 2013 Service Cost $ 1,116 $ 891 $ 1,139 Interest Cost 2,973 2,852 2,730 Expected Return on Plan Assets (2,993 ) (2,603 ) (2,378 ) Amortizations: Prior Service Cost (Credits) 608 152 (283 ) Actuarial Loss 1,342 974 1,738 Net Periodic Benefit Cost 3,046 2,266 2,946 Capitalized Benefit Costs (1,043 ) (722 ) (1,172 ) Deferred Benefit Costs (256 ) — — Total Net Periodic Benefit Expense $ 1,747 $ 1,544 $ 1,774
Schedule Defined Benefit Plans, Changes in Regulatory Assets and Accumulated Other Comprehensive Income (Loss)	Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands): Regulatory Assets Accumulated Other Comprehensive Loss (pre-tax) Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Balance at January 1, 2014 $ 42,632 $ 16,652 $ 27,574 $ 3,710 Amounts Arising during the Period: Net Actuarial Loss 31,075 7,826 14,698 2,269 Prior Service Cost 486 4,146 14 981 Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (2,841 ) (628 ) (2,819 ) (187 ) Prior Service (Cost) Credit (175 ) (133 ) 1 (18 ) Balance at December 31, 2014 71,177 27,863 39,468 6,755 Amounts Arising during the Period: Net Actuarial (Loss)/Gain (463 ) (3,155 ) 59 (2,285 ) Prior Service Credit — (499 ) — (106 ) Amounts Amortized to Net Periodic Costs: Net Actuarial Loss (6,079 ) (1,107 ) (4,452 ) (221 ) Prior Service Cost (203 ) (7,755 ) (9 ) (2,081 ) Balance at December 31, 2015 $ 64,432 $ 15,347 $ 35,066 $ 2,062
Schedule of Amounts in Regulatory Assets to be Recognized over Next Fiscal Year	The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2016 are as follows (in thousands): Pension Benefits Other Postretirement Benefits Prior Service Cost/(Credit) $ 203 $ (257 ) Net Actuarial Loss $ 5,488 $ 998
Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year	The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2016 are as follows (in thousands): Pension Benefits Other Postretirement Benefits Prior Service Cost/(Credit) $ 9 $ (88 ) Net Actuarial Loss $ 3,747 $ 179
Schedule of Net Funded Status and Amounts Recognized in Balance Sheet	A reconciliation of the plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in SJI's consolidated balance sheets follows (in thousands): Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 Change in Benefit Obligations: Benefit Obligation at Beginning of Year $ 265,434 $ 216,395 $ 75,592 $ 62,355 Service Cost 5,337 4,510 1,116 891 Interest Cost 11,168 10,735 2,973 2,852 Actuarial (Gain) Loss (17,349 ) 42,746 (8,591 ) 8,151 Retiree Contributions — — 700 488 Plan Amendments — 550 (9,899 ) 5,143 Benefits Paid (10,395 ) (9,502 ) (4,461 ) (4,288 ) Benefit Obligation at End of Year $ 254,195 $ 265,434 $ 57,430 $ 75,592 Change in Plan Assets: Fair Value of Plan Assets at Beginning of Year $ 180,523 $ 178,093 $ 43,222 $ 41,653 Actual Return on Plan Assets (2,321 ) 10,397 (423 ) 596 Employer Contributions 17,017 1,535 8,721 4,773 Retiree Contributions — — 700 488 Benefits Paid (10,395 ) (9,502 ) (4,461 ) (4,288 ) Fair Value of Plan Assets at End of Year $ 184,824 $ 180,523 $ 47,759 $ 43,222 Funded Status at End of Year: $ (69,371 ) $ (84,911 ) $ (9,671 ) $ (32,370 ) Amounts Related to Unconsolidated Affiliate 204 57 509 301 Accrued Net Benefit Cost at End of Year $ (69,167 ) $ (84,854 ) $ (9,162 ) $ (32,069 ) Amounts Recognized in the Statement of Financial Position Consist of: Current Liabilities $ (2,261 ) $ (1,550 ) $ — $ — Noncurrent Liabilities (66,906 ) (83,304 ) (9,162 ) (32,069 ) Net Amount Recognized at End of Year $ (69,167 ) $ (84,854 ) $ (9,162 ) $ (32,069 ) Amounts Recognized in Regulatory Assets Consist of: Prior Service Costs $ 741 $ 944 $ (3,289 ) $ 4,965 Net Actuarial Loss 63,691 70,233 18,636 22,898 $ 64,432 $ 71,177 $ 15,347 $ 27,863 Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax): Prior Service Costs $ 77 $ 86 $ (1,074 ) $ 1,113 Net Actuarial Loss 34,989 39,382 3,136 5,642 $ 35,066 $ 39,468 $ 2,062 $ 6,755
Schedule of Assumptions Used	The weighted-average assumptions used to determine benefit obligations at December 31 were: Pension Benefits Other Postretirement Benefits 2015 2014 2015 2014 Discount Rate 4.83 % 4.25 % 4.73 % 4.20 % 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 2015 2014 2013 2015 2014 2013 Discount Rate 4.25 % 5.09 % 4.26 % 4.20 % 4.91 % 4.14 % Expected Long-Term Return on Plan Assets 7.75 % 7.75 % 7.50 % 6.25 % 6.25 % 6.60 % Rate of Compensation Increase 3.50 % 3.50 % 3.25 % 3.50 % 3.50 % 3.25 %
Schedule of Health Care Cost Trend Rates	The assumed health care cost trend rates at December 31 were: 2015 2014 Medical Care and Drug Cost Trend Rate Assumed for Next Year N/A 7.00 % Dental Care Cost Trend Rate Assumed for Next Year N/A 4.75 % Rate to which Cost Trend Rates are Assumed to Decline (the Ultimate Trend Rate) N/A 4.75 % Year that the Rate Reaches the Ultimate Trend Rate N/A 2023
Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates	A one-percentage-point change in assumed health care cost trend rates would have the following effects (in thousands): 1-Percentage- Point Increase 1-Percentage- Point Decrease Effect on the Total of Service and Interest Cost $ 199 $ (160 )
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets	Fair Value Measurement Using Significant Unobservable Inputs (Level 3) (In thousands) Guaranteed Private Insurance Hedge Equity Real Contract Funds Funds Estate Total Balance at January 1, 2014 $ 11,322 $ 4,154 $ 3,046 $ 6,741 $ 25,263 Actual return on plan assets: Relating to assets still held at the reporting date 498 177 (24 ) 735 1,386 Relating to assets sold during the period 13 — 325 — 338 Purchases, Sales and Settlements (921 ) — 269 — (652 ) Balance at December 31, 2014 10,912 4,331 3,616 7,476 26,335 Actual return on plan assets: Relating to assets still held at the reporting date (106 ) (172 ) (302 ) 1,039 459 Relating to assets sold during the period 25 — 429 — 454 Purchases, Sales and Settlements (871 ) — 569 — (302 ) Balance at December 31, 2015 $ 9,960 $ 4,159 $ 4,312 $ 8,515 $ 26,946
Schedule of Expected 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 2016 $ 11,409 $ 4,458 2017 $ 11,846 $ 4,427 2018 $ 12,376 $ 4,363 2019 $ 13,374 $ 4,406 2020 $ 13,954 $ 4,519 2021 - 2024 $ 82,139 $ 21,933
Pension Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of Allocation of Plan Assets	The fair values of SJI's pension plan assets at December 31, 2015 and 2014 by asset category are as follows (in thousands): Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015 Cash / Cash Equivalents: Cash $ 35 $ 35 $ — $ — Common/Collective Trust Funds (a) 858 — 858 — STIF-Type Instrument (b) 1,360 — 1,360 — Equity securities: Common/Collective Trust Funds - U.S. (a) 52,058 — 52,058 — Common/Collective Trust Funds - International (a) 33,236 — 33,236 — U.S. Large-Cap (c) 14,305 14,305 — — U.S. Mid-Cap (c) 3,407 3,407 — — U.S. Small-Cap (c) 260 260 — — International (c) 1,695 1,695 — — Fixed Income: Common/Collective Trust Funds (a) 50,664 — 50,664 — Guaranteed Insurance Contract (d) 9,960 — — 9,960 Hedge Funds (e) 4,159 — — 4,159 Other types of investments: Private Equity Fund (f) 4,312 — — 4,312 Common/Collective Trust Fund - Real Estate (g) 8,515 — — 8,515 Total $ 184,824 $ 19,702 $ 138,176 $ 26,946 Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2014 Cash / Cash Equivalents: Common/Collective Trust Funds (a) $ 692 $ — $ 692 $ — STIF-Type Instrument (b) 1,252 — 1,252 — Equity securities: Common/Collective Trust Funds - U.S. (a) 51,197 — 51,197 — Common/Collective Trust Funds - International (a) 30,963 — 30,963 — U.S. Large-Cap (c) 12,961 12,961 — — U.S. Mid-Cap (c) 5,147 5,147 — — U.S. Small-Cap (c) 232 232 — — International (c) 3,369 3,369 — — Fixed Income: Common/Collective Trust Funds (a) 48,375 — 48,375 — Guaranteed Insurance Contract (d) 10,912 — — 10,912 Hedge Funds (e) 4,331 — — 4,331 Other types of investments: Private Equity Fund (f) 3,616 — — 3,616 Common/Collective Trust Fund - Real Estate (g) 7,476 — — 7,476 Total $ 180,523 $ 21,709 $ 132,479 $ 26,335 (a) This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable. Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments. (b) This category represents short-term investment funds held for the purpose of funding disbursement payment arrangements. Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information. Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments. (c) This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy. These common stocks are actively traded on exchanges and price quotes for these shares are readily available. These common stocks are classified as Level 1 investments. (d) This category represents SJI's Group Annuity contracts with a nationally recognized life insurance company. The contracts are the assets of the plan, while the underlying assets of the contracts are owned by the contract holder. Valuation is based on a formula and calculation specified within the contract. Since the valuation is based on the reporting entity's own assumptions, these contracts are classified as Level 3 investments. (e) This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments. (f) This category represents a limited partnership/commingled trust which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 to 120 day lag and, therefore, the value reported herein represents the market value as of June 30 or September 30, 2015 and 2014, respectively, with cash flow changes through December applied. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments. Fund investments are illiquid and resale is restricted. These funds are classified as Level 3 investments. (g) This category represents real estate common/collective trust fund investments through a commingled employee benefit trust. These commingled funds are part of a direct investment in a pool of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals from sources with professional qualifications. Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments.
Other Postretirement Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of Allocation of Plan Assets	The fair values of SJI's other postretirement benefit plan assets at December 31, 2015 and 2014 by asset category are as follows (in thousands): Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2015: Cash $ 26 $ 26 $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) $ 13,522 $ — $ 13,522 $ — Common/Collective Trust Funds - International (a) 8,313 — 8,313 — Mutual Fund - U.S. (b) 1,309 1,309 — — Mutual Funds - International (b) 983 983 — — Fixed Income: Common/Collective Trust Funds - Bonds (a) 13,187 — 13,187 — Mutual Funds - Bonds (b) 1,441 1,441 — — Other Types of Investments: Mutual Funds - REITS (b) 152 152 — — Company Owned Life Insurance (c) 8,826 — 8,826 — Total $ 47,759 $ 3,911 $ 43,848 $ — Asset Category Total Level 1 Level 2 Level 3 As of December 31, 2014: Cash $ 153 $ 153 $ — $ — Equity Securities: Common/Collective Trust Funds - U.S. (a) $ 10,493 $ — $ 10,493 $ — Common/Collective Trust Funds - International (a) 7,373 — 7,373 — Mutual Fund - U.S. (b) 4,723 4,723 — — Mutual Funds - International (b) 1,795 1,795 — — Fixed Income: Common/Collective Trust Funds - Bonds (a) 11,597 — 11,597 — Mutual Funds - Bonds (b) 2,820 2,820 — — Other Types of Investments: Mutual Funds - REITS (b) 308 308 — — Company Owned Life Insurance (c) 3,960 — 3,960 — Total $ 43,222 $ 9,799 $ 33,423 $ — (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.

LINES OF CREDIT (Tables)

LINES OF CREDIT (Tables)	12 Months Ended
	Dec. 31, 2015
Line of Credit Facility [Abstract]
Schedule of lines of credit	Credit facilities and available liquidity as of December 31, 2015 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 136,600 (A) $ 63,400 May 2018 Uncommitted Bank Lines 10,000 — 10,000 August 2016 Total SJG 210,000 136,600 73,400 SJI: Revolving Credit Facility 400,000 305,400 (B) 94,600 February 2018 Total SJI 400,000 305,400 94,600 Total $ 610,000 $ 442,000 $ 168,000 (A) Includes letters of credit outstanding in the amount of $2.2 million . (B) Includes letters of credit outstanding in the amount of $8.1 million .

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	Outstanding Long-Term Debt at December 31 consisted of the following: 2015 2014 Long-Term Debt (A): South Jersey Gas Company: First Mortgage Bonds: (B) 5.387% Series due 2015 (C) $ — $ 10,000 5.437% Series due 2016 10,000 10,000 4.6% Series due 2016 17,000 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 50,000 50,000 3.03% Series due 2024 35,000 35,000 3.63% Series due 2025 (D) 9,091 10,000 4.84% Series due 2026 15,000 15,000 4.93% Series due 2026 45,000 45,000 4.03% Series due 2027 45,000 45,000 4.01% Series due 2030 50,000 50,000 4.23% Series due 2030 30,000 30,000 3.74% Series due 2032 35,000 35,000 5.55% Series due 2033 32,000 32,000 6.213% Series due 2034 10,000 10,000 5.45% Series due 2035 10,000 10,000 Series A 2006 Bonds at variable rates due 2036 (E) 24,900 25,000 SJG Term Facility (F) 139,000 59,000 Marina Energy LLC: (G) Series A 2001 Bonds at variable rates due 2031 20,000 20,000 Series B 2001 Bonds at variable rates due 2021 25,000 25,000 Series A 2006 Bonds at variable rates due 2036 16,400 16,400 South Jersey Industries: 2.39% Series A 2012 Notes due 2015 (H) — 64,000 2.71% Series B 2012 Notes due 2017 16,000 16,000 3.05% Series due 2019 (I) 60,000 60,000 3.05% Series due 2019 (I) 30,000 30,000 3.05% Series due 2019 (I) 50,000 50,000 3.46% Series C 2012 Notes due 2022 35,000 35,000 Series Notes at variable rates due 2019 (I) 40,000 40,000 Series Notes at variable rates due 2019 (I) 60,000 60,000 South Jersey Industries Term Loan at variable rates due 2015 (J) — 50,000 South Jersey Industries Term Loan at variable rates due 2020 (J) 50,000 — ACB Energy Partners, LLC: 7.60 % Loan & Security Agreement (K) 12,735 — Other Energy Project Debt (L): 4.83 % ACLE 3,551 — 4.83 % SCLE 1,738 — 4.83 % SXLE 3,433 — Total Long-Term Debt Outstanding $ 1,035,848 $ 1,009,400 Less Current Maturities (29,454 ) (149,909 ) Total Long-Term Debt $ 1,006,394 $ 859,491 (A) Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2016, $29,454 ; 2017, $172,558 ; 2018, $40,667 ; 2019, $260,783 ; and 2020, $74,476 . (B) The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant. (C) In August 2015, SJG retired $10.0 million aggregate principal amount of 5.387% Medium Term Notes (MTN's) at maturity. (D) In December 2015, SJG paid $0.9 million toward the principal amount of 3.63% MTN's due December 2025. (E) In September 2015, SJG paid $0.1 million toward the principal amount of variable rate demand bonds due February 2036. These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2015 was 0.03% . 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. (F) In June 2014, SJG entered into a $200.0 million multiple-draw term facility offered by a syndicate of banks which expires in June 2017. SJG can draw under this facility through June 2016 and this facility bears 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. (G) Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2015 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.04% , 0.47% and 0.04% respectively. The interest rate on all but $39.0 million of the bonds has been effectively fixed via interest rate swaps at 4.22% until January 2026. These bonds contain no financial covenants. Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in March, 2016. The Company has plans to renew this letter of credit facility upon expiration. (H) In June 2015, SJI redeemed at maturity $64.0 million aggregate principal amount of 2.39% Senior Notes. (I) In June 2014, SJI entered into a Note Purchase Agreement that provided for SJI to issue an aggregate of $240.0 million of medium term notes, all of which were issued as follows: (a) in June 2014, SJI issued $60.0 million aggregate principal amount of 3.05% Senior Notes due June 2019, and $40.0 million aggregate principal amount of Floating Rate Senior Notes due June 2019; (b) in August 2014, SJI issued $30.0 million aggregate principal amount of 3.05% Senior Notes due August 2019; and (c) in September 2014, SJI issued $50.0 million aggregate principal amount of 3.05% Senior Notes due September 2019, and $60.0 million aggregate principal amount of Floating Rate Senior Notes due September 2019. At December 31, 2015 , the floating rate was 1.93% . (J) In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million , which matures in October 2020. This agreement replaced existing facilities that expired in October 2015. The variable rate at December 31, 2015 was 1.28% . (K) ACB has a Loan and Security Agreement (“LSA”) with a third party to borrow up to $16.0 million . Under the LSA, ACB pays principal and interest (at a fixed rate of 7.60% ) in equal quarterly installments that began in February 2011 and run through February 2021. As of December 31, 2014, ACB was a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest. In December 2015, ACB became a wholly-owned subsidiary of Marina (see Note 3); as such, the remaining outstanding debt of $12.7 million is included on the consolidated balance sheets as of December 31, 2015. The remaining debt was paid in January 2016 (see Note 19). (L) ACLE, SCLE and SXLE (the "Other Energy Projects") have long-term debt agreements with a third party to borrow up to $10.0 million . Under the debt agreement, the Other Energy Projects pay principal and interest (at a fixed rate of 4.83% ) in equal installments that began December 2013 and run through December 2020. As of December 31, 2014, the Other Energy Projects were wholly-owned subsidiaries of Energenic, of which Marina had a 50% equity interest. SJI had agreements to guarantee 50% of the outstanding debt, which was $4.7 million as of December 31, 2014, and the Company had recorded $0.3 million for the fair value of the guarantees on the consolidated balance sheets as of December 31, 2014. In December 2015, the Other Energy Projects became wholly-owned subsidiaries of Marina (see Note 3); as such, the remaining outstanding debt of $8.7 million is included on the consolidated balance sheets as of December 31, 2015.

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Schedule of Environmental Loss Contingencies	The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands): 2015 2014 Beginning of Year $ 128,172 $ 123,429 Accruals 19,489 18,533 Expenditures (21,038 ) (13,790 ) End of Year $ 126,623 $ 128,172

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of notional amounts of outstanding derivative positions	As of December 31, 2015 , SJI's active interest rate swaps were as follows: Notional Amount Fixed Interest Rate Start Date Maturity Type of Debt Obligor $ 14,500,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 500,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 330,000 3.905% 3/17/2006 1/15/2026 Tax-exempt Marina $ 7,100,000 4.895% 2/1/2006 2/1/2016 (A) Taxable Marina $ 12,500,000 3.430% 12/1/2006 2/1/2036 Tax-exempt SJG $ 12,500,000 3.430% 12/1/2006 2/1/2036 Tax-exempt SJG
Fair value of derivative instruments	The fair values of all derivative instruments, as reflected in the consolidated balance sheets as of December 31, are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP 2015 2014 Assets Liabilities Assets Liabilities Energy-related commodity contracts: Derivatives – Energy Related – Current 83,093 90,708 $ 85,368 $ 109,744 Derivatives – Energy Related – Non-Current 16,238 21,697 13,905 19,926 Interest rate contracts: Derivatives - Other — 10,943 — 10,732 Total derivatives not designated as hedging instruments under GAAP 99,331 123,348 99,273 140,402 Total Derivatives $ 99,331 $ 123,348 $ 99,273 $ 140,402
Offsetting arrangements	As of December 31, 2015 and 2014 , information related to these offsetting arrangements were as follows (in thousands): As of December 31, 2015 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets 99,331 — $ 99,331 (35,491 ) (A) — $ 63,840 Derivatives - Energy Related Liabilities (112,405 ) — $ (112,405 ) 35,491 (B) 23,045 $ (53,869 ) Derivatives - Other (10,943 ) — $ (10,943 ) — — $ (10,943 ) As of December 31, 2014 Description Gross amounts of recognized assets/liabilities Gross amount offset in the balance sheet Net amounts of assets/liabilities in balance sheet Gross amounts not offset in the balance sheet Net amount Financial Instruments Cash Collateral Posted Derivatives - Energy Related Assets 99,273 — $ 99,273 (39,747 ) (A) — $ 59,526 Derivatives - Energy Related Liabilities (129,670 ) — $ (129,670 ) 39,747 (B) 53,897 $ (36,026 ) Derivatives - Other (10,732 ) — $ (10,732 ) — — $ (10,732 ) (A) The balances at December 31, 2015 and 2014 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at December 31, 2015 and 2014 were related to derivative assets which can be net settled against derivative liabilities.
Derivatives in cash flow hedging relationships	The effect of derivative instruments on the statements of consolidated income and comprehensive income for the year ended December 31 is as follows (in thousands): Derivatives in Cash Flow Hedging Relationships 2015 2014 2013 Interest Rate Contracts: Losses recognized in AOCL on effective portion $ — $ — $ — Losses reclassified from AOCL into income (a) $ (551 ) $ (419 ) $ (448 ) Losses recognized in income on ineffective portion (a) — — — (a) Included in Interest Charges Derivatives Not Designated as Hedging Instruments under GAAP 2015 2014 2013 Gains (losses) on energy-related commodity contracts (a) $ 8,401 $ (6,592 ) $ (25,823 ) Gains (losses) on interest rate contracts (b) 96 (467 ) 2,760 Total $ 8,497 $ (7,059 ) $ (23,063 ) (a) Included in Operating Revenues - Nonutility (b) Included in Interest Charges

FAIR VALUE OF FINANCIAL ASSET45

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 14,810 $ 2,925 $ 11,885 $ — Derivatives – Energy Related Assets (B) 99,331 16,006 24,730 58,595 $ 114,141 $ 18,931 $ 36,615 $ 58,595 Liabilities Derivatives – Energy Related Liabilities (B) $ 112,405 $ 42,170 $ 11,008 $ 59,227 Derivatives – Other (C) 10,943 — 10,943 — $ 123,348 $ 42,170 $ 21,951 $ 59,227 As of December 31, 2014 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 8,922 $ 5,952 $ 2,970 $ — Derivatives – Energy Related Assets (B) 99,273 21,675 43,093 34,505 $ 108,195 $ 27,627 $ 46,063 $ 34,505 Liabilities Derivatives – Energy Related Liabilities (B) $ 129,670 $ 49,009 $ 40,548 $ 40,113 Derivatives – Other (C) 10,732 — 10,732 — $ 140,402 $ 49,009 $ 51,280 $ 40,113 (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 forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. (C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.
Quantitative information regarding significant unobservable inputs in Level 3 fair value measurements	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands, except for ranges): Type Fair Value at December 31, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $ 29,459 $ 31,733 Discounted Cash Flow Forward price (per dt) $(0.77) - $10.00 [$(2.15)] (A) Forward Contract - Electric $ 29,136 $ 27,494 Discounted Cash Flow Fixed electric load profile (on-peak) 8.47% - 100.00% [56.20%] (B) Fixed electric load profile (off-peak) 0.00% - 91.53% [43.80%] (B) Type Fair Value at December 31, 2014 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $ 26,485 $ 33,882 Discounted Cash Flow Forward price (per dt) $(2.04) - $7.83 [$(0.30)] (A) Forward Contract - Electric $ 8,020 $ 6,231 Discounted Cash Flow Fixed electric load profile (on-peak) 8.06% - 100.00% [55.97%] (B) Fixed electric load profile (off-peak) 0.00% - 91.94% [44.03%] (B)
Changes in fair value of significant unobservable inputs	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 2015 , using significant unobservable inputs (Level 3), are as follows (in thousands): Year Ended December 31, 2015 Balance at January 1, 2015 $ (5,608 ) Other changes in fair value from continuing and new contracts, net (5,069 ) Transfers in to/(out of) of Level 3 (A) 7,402 Settlements 2,643 Balance at December 31, 2015 $ (632 ) Year Ended December 31, 2014 Balance at January 1, 2014 $ 8,095 Other changes in fair value from continuing and new contracts, net (17,153 ) Settlements 3,450 Balance at December 31, 2014 $ (5,608 ) (A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the year ended December 31, 2015, $7.4 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data, which is assessed quarterly by management.

ACCUMULATED OTHER COMPREHENSI46

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) (Tables)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Schedule of changes in accumulated other comprehensive loss (AOCL)	The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2015 (in thousands): Postretirement Liability Adjustment Unrealized Gain (Loss) on Derivatives-Other Unrealized Gain (Loss) on Available-for-Sale Securities Other Comprehensive Income (Loss) of Affiliated Companies Total Balance at January 1, 2015 (a) $ (27,663 ) $ (2,450 ) $ (75 ) $ (70 ) $ (30,258 ) Other comprehensive income before reclassifications 1,427 — (76 ) — 1,351 Amounts reclassified from AOCL (b) 4,091 321 23 (27 ) 4,408 Net current period other comprehensive income 5,518 321 (53 ) (27 ) 5,759 Balance at December 31, 2015 (a) $ (22,145 ) $ (2,129 ) $ (128 ) $ (97 ) $ (24,499 ) (a) Determined using a combined average statutory tax rate of 40% . (b) See table below. The following table provides details about reclassifications out of AOCL for the year ended December 31, 2015 (in thousands): Amounts Reclassified from AOCL Affected Line Item in the Condensed Consolidated Statements of Income For the Year Ended December 31, 2015 Actuarial Loss on Postretirement Benefits $ 6,763 Operating Expenses: Operations Income Taxes (2,672 ) Income Taxes (a) $ 4,091 Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 551 Interest Charges Income Taxes (230 ) Income Taxes (a) $ 321 Unrealized Loss on Available-for-Sale Securities $ 37 Other Income Income Taxes (14 ) Income Taxes (a) $ 23 Income of Affiliated Companies $ (45 ) Equity in Loss of Affiliated Companies Income Taxes 18 Income Taxes (a) $ (27 ) Losses from reclassifications for the period net of tax $ 4,408 (a) Determined using a combined average statutory tax rate of 40% .

Quarterly Financial Data (Una47

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Schedule of quarterly results	2015 Quarter Ended 2014 Quarter Ended March 31 June 30 Sept. 30 Dec. 31 March 31 June 30 Sept. 30 Dec. 31 Operating Revenues $ 382,952 $ 177,710 $ 141,062 $ 257,844 $ 350,201 $ 133,271 $ 122,427 $ 281,097 Expenses: Cost of Sales - (Excluding depreciation) 241,707 90,945 99,124 127,566 228,138 78,947 76,073 153,794 Operations and Maintenance Including Fixed Charges 71,279 62,634 63,867 71,148 64,684 56,174 56,039 69,384 Income Taxes 16,613 (3,279 ) (10,968 ) (1,006 ) 11,869 (9,510 ) (8,325 ) 10,415 Energy and Other Taxes 2,196 1,265 1,231 1,334 1,953 1,241 1,196 1,330 Total Expenses 331,795 151,565 153,254 199,042 306,644 126,852 124,983 234,923 Other Income and Expense 2,696 (12,804 ) (340 ) (7,854 ) 4,654 3,282 (1,720 ) (2,182 ) Income (Loss) from Continuing Operations 53,853 13,341 (12,532 ) 50,948 48,211 9,701 (4,276 ) 43,992 Loss from Discontinued Operations - (Net of tax benefit) (276 ) (74 ) (91 ) (62 ) (313 ) (80 ) (120 ) (69 ) Net Income (Loss) $ 53,577 $ 13,267 $ (12,623 ) $ 50,886 $ 47,898 $ 9,621 $ (4,396 ) $ 43,923 Basic Earnings Per Common Share: Continuing Operations $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 $ 0.74 $ 0.15 $ (0.07 ) $ 0.66 Discontinued Operations — — — — — — — — Basic Earnings Per Common Share $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 $ 0.74 $ 0.15 $ (0.07 ) $ 0.66 Average Shares of Common Stock Outstanding - Basic 68,397 68,467 68,607 69,460 65,530 65,926 66,332 67,304 Diluted Earnings Per Common Share: Continuing Operations $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 $ 0.74 $ 0.15 $ (0.07 ) $ 0.65 Discontinued Operations — — — — — — — — Diluted Earnings Per Common Share $ 0.79 $ 0.19 $ (0.18 ) $ 0.73 $ 0.74 $ 0.15 $ (0.07 ) $ 0.65 Average Shares of Common Stock Outstanding - Diluted 68,618 68,653 68,607 69,646 65,684 66,074 66,332 67,454

SUMMARY OF SIGNIFICANT ACCOUN48

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)		May. 08, 2015	Feb. 26, 2015shares	Dec. 31, 2015USD ($)shares	Dec. 31, 2014USD ($)shares	Dec. 31, 2013USD ($)	Dec. 31, 2015USD ($)shares	Sep. 30, 2014	Feb. 25, 2015shares
Schedule of Equity Method Investments [Line Items]
Loss from equity method investments, net of tax				$ 27,812,000	$ 7,785,000	$ (1,585,000)
Goodwill				8,880,000	0		$ 8,880,000
Intangible assets				$ 21,553,000	$ 0		$ 21,553,000
Common Stock, authorized (in shares) | shares			120,000,000	120,000,000	120,000,000		120,000,000		60,000,000
Stock split, conversion ratio		2	2
Equity investment impairments					$ 0	0
TEFA and PUA included in both utility revenue and cost of sales				$ 1,200,000	1,100,000	1,200,000
Transitional Energy Facility Assessment						4,000,000
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
AROs as of January 1,				42,502,000	41,687,000
Accretion				1,675,000	1,612,000
Additions				802,000	664,000
Settlements				(1,110,000)	(1,461,000)
Revisions in Estimated Cash Flows	[1]			14,074,000	0
ARO's as of December 31,				$ 57,943,000	$ 42,502,000	$ 41,687,000	$ 57,943,000
Composite annual rate for all depreciable utility property				2.20%	2.20%	2.30%
Useful life				50 years
Composite depreciate rate							2.10%	2.40%
Interest capitalized				$ 4,900,000	$ 4,600,000	$ 8,700,000
Impairment of nonutility property and equipment and other noncurrent assets				0	0	$ 0
Amount of costs related to interests in proved and unproved properties in Pennsylvania, net of amortization				$ 8,900,000	$ 8,900,000		$ 8,900,000
Treasury stock held (in shares) | shares				236,571	263,578		236,571
Minimum [Member]
Schedule of Equity Method Investments [Line Items]
Useful life of intangible assets				2 years
Maximum [Member]
Schedule of Equity Method Investments [Line Items]
Useful life of intangible assets				20 years
Other Noncurrent Assets [Member]
Schedule of Equity Method Investments [Line Items]
Goodwill				$ 8,900,000	$ 0		$ 8,900,000
Intangible assets				21,600,000			$ 21,600,000
Energenic US LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity investment impairments				$ 7,700,000
[1]	The revision in estimated cash flows reflects an increase in the contractual cost to settle ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.

STOCK-BASED COMPENSATION PLAN49

STOCK-BASED COMPENSATION PLAN (Details) - USD ($) $ / shares in Units, $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of options granted (in shares)			0	0	0
Fair Value Per Share (in USD per share)		$ 26.89	$ 24.40	$ 24.40		$ 26.89
Expected volatility, measurement period			3 years
Net Expense			$ 1,681	$ 1,746	$ 2,764
Capitalized			$ (216)	$ (147)	(237)
Unrecognized compensation cost of awards granted under the plan						$ 2,900
Weighted average period over which unrecognized compensation cost is to be recognized (in years)			1 year 9 months 18 days
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)		$ 26.89	$ 24.40
Granted (in USD per share)			28.67
Vested (in USD per share)	[1]		24.57
Cancelled/Forfeited (in USD per share)	[2]		26.56
Nonvested Shares Outstanding, ending balance (in USD per share)			$ 26.89	$ 24.40
Cost [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense			$ 1,897	$ 1,893	$ 3,001
EPS [Member] | Cost [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense			$ (1,200)	$ (1,100)
Officers and Key Employees [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)			158,929	136,526	112,928
Vesting period of shares (in shares)			3 years
The range of the actual amount of shares that ultimately vest of the original share units granted (in hundredths)			0% to 200%
Actual amount of shares that ultimately vest of the original share units granted, minimum			0.00%
Actual amount of shares that ultimately vest of the original share units granted, maximum			200.00%
Shares Outstanding (in shares)		226,191	223,876	223,876		226,191
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)		226,191	223,876
Granted (in shares)			158,929	136,526	112,928
Vested (in shares)	[1]		(91,244)
Cancelled/Forfeited (in shares)	[2]		(65,370)
Nonvested Shares Outstanding, ending balance (in shares)			226,191	223,876
Weighted Average Fair Value
Number of shares awarded during the period (in shares)			0	0	66,077
Market value of shares awarded (in shares)					$ 3,300
Officers and Key Employees [Member] | Forecast [Member]
Weighted Average Fair Value
Number of shares awarded during the period (in shares)		0
Officers and Key Employees [Member] | Cost [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense			$ 1,128	$ 1,260	2,236
Officers and Key Employees [Member] | 2014 - TSR [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)		51,349	51,349			51,349
Fair Value Per Share (in USD per share)		$ 21.31	$ 21.31			$ 21.31
Expected Volatility			20.00%
Risk-Free Interest Rate			0.80%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)		51,349
Nonvested Shares Outstanding, ending balance (in shares)			51,349
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)		$ 21.31
Nonvested Shares Outstanding, ending balance (in USD per share)			$ 21.31
Officers and Key Employees [Member] | 2014 - EPS [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)		51,349	51,349			51,349
Fair Value Per Share (in USD per share)		$ 27.22	$ 27.22			$ 27.22
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)		51,349
Nonvested Shares Outstanding, ending balance (in shares)			51,349
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)		$ 27.22
Nonvested Shares Outstanding, ending balance (in USD per share)			$ 27.22
Officers and Key Employees [Member] | 2015 -TSR [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)		34,574	34,574			34,574
Fair Value Per Share (in USD per share)		$ 26.31	$ 26.31			$ 26.31
Expected Volatility			16.00%
Risk-Free Interest Rate			1.10%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)		34,574
Nonvested Shares Outstanding, ending balance (in shares)			34,574
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)		$ 26.31
Nonvested Shares Outstanding, ending balance (in USD per share)			$ 26.31
Officers and Key Employees [Member] | 2015- EPS, ROE, Time [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)		88,919	88,919			88,919
Fair Value Per Share (in USD per share)		$ 29.47	$ 29.47			$ 29.47
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)		88,919
Nonvested Shares Outstanding, ending balance (in shares)			88,919
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)		$ 29.47
Nonvested Shares Outstanding, ending balance (in USD per share)			$ 29.47
Directors [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)			26,338
Vesting period of shares (in shares)			12 months
Shares Outstanding (in shares)		26,338	23,220	23,220		26,338
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)		26,338	23,220
Granted (in shares)			26,338
Vested (in shares)	[1]		(23,220)
Cancelled/Forfeited (in shares)	[2]		0
Nonvested Shares Outstanding, ending balance (in shares)			26,338	23,220
Weighted Average Fair Value
Market value of shares awarded (in shares)			$ 800	$ 600	600
Directors [Member] | Cost [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Net Expense			$ 769	$ 633	$ 765
Directors [Member] | 2015 [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)		26,338	26,338			26,338
Fair Value Per Share (in USD per share)		$ 29.21	$ 29.21			$ 29.21
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Nonvested Shares Outstanding, beginning balance (in shares)		26,338
Nonvested Shares Outstanding, ending balance (in shares)			26,338
Weighted Average Fair Value
Nonvested Shares Outstanding, beginning balance (in USD per share)		$ 29.21
Nonvested Shares Outstanding, ending balance (in USD per share)			$ 29.21
Stock Appreciation Rights (SARs) [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)			0	0	0
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)			0	0	0
Restricted Stock [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Return on equity award threshold			7.00%
Restricted Stock [Member] | Officers and Key Employees [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)			47,678
Vesting period of shares (in shares)			3 years
Payout limit, percentage			100.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)			47,678
Restricted Stock [Member] | Directors [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of awards granted (in shares)			26,338	23,220	24,570
Percent of shares vested, Directors						100.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}
Granted (in shares)			26,338	23,220	24,570
[1]	*
[2]	Represents shares forfeited as a result of retirements prior to the satisfaction of service conditions.

AFFILIATIONS AND DISCONTINUED50

AFFILIATIONS AND DISCONTINUED OPERATIONS - Summarized Financial Information (Details) $ in Thousands	Dec. 31, 2015USD ($)investmentagreement	Dec. 31, 2015USD ($)investmentagreement	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Affiliations [Abstract]
Notes receivable from affiliate	$ 16,400	$ 16,400	$ 51,500
Notes receivable from affiliate, current	3,134	3,134	14,657
Notes receivable from third party	35,439	35,439	7,882
Net investments in (repayments from) unconsolidated affiliates		18,000	(2,400)	$ (9,600)
Notes receivable secured by property, plant, and equipment of affiliates	13,700	$ 13,700
Interest accrual on secured notes receivable		7.50%
Repayment period, latest date		2,025
Unsecured notes receivable	2,700	$ 2,700
Net asset - included in investment in affiliates and other noncurrent liabilities	17,000	17,000
Combined equity contributions and the notes receivable - affiliate		33,400
Equity Method Investment, Summarized Financial Information [Abstract]
Goodwill	8,880	8,880	0
Current assets	21,914	21,914	46,683
Noncurrent assets	117,091	117,091	478,240
Current liabilities	47,797	47,797	75,260
Noncurrent liabilities	112,438	112,438	315,801
Revenues		163,479	207,031	178,026
Cost of sales		86,452	107,042	91,228
(Loss) Income from continuing operations		(56,962)	(11,666)	6,229
Net (Loss) Income		$ (56,962)	$ (11,666)	6,229
Energenic US LLC [Member]
Affiliations [Abstract]
Gain on project prior to exchange	$ 2,700
Potato Creek, LLC (Potato Creek) [Member]
Affiliations [Abstract]
Equity interest	30.00%	30.00%
Marina Energy LLC [Member] | Energenic US LLC [Member]
Affiliations [Abstract]
Equity interest	50.00%	50.00%
Number of distribution and purchase agreements | agreement	2	2
Number of investments owned | investment	8	8
Notes receivable from affiliate	$ 19,500	$ 19,500
Notes receivable from affiliate, current	$ 1,800	$ 1,800
Percentage of fair value of assets acquired and liabilities assumed	100.00%	100.00%
Consideration received	$ 46,100
Fair value of the interest in Partner Projects exchanged	14,600
Equity Method Investment, Summarized Financial Information [Abstract]
Current assets (excluding inventory)	7,804	$ 7,804
Inventory	3,154	3,154
Note Receivable Received	19,504	19,504
Fixed Assets	40,854	40,854
Identifiable Intangibles	21,553	21,553
Goodwill	8,880	8,880
Noncurrent assets	1,873	1,873
Current liabilities	(8,196)	(8,196)
Current Liabilities	16,986	16,986
Long-Term Debt, including current portion	(21,457)	(21,457)
Capital Lease Payable	(10,357)	(10,357)
Noncurrent liabilities	(572)	(572)
Fair Value of Consolidated Assets and Liabilities of Acquired Projects	$ 46,054	$ 46,054
Marina Energy LLC [Member] | Energenic US LLC [Member] | Co-venturer [Member]
Affiliations [Abstract]
Number of investments owned | investment	7	7
Fair value of the interest in Partner Projects exchanged	$ 31,500
Marina Energy LLC [Member] | LVE Energy Partners, LLC (LVE) [Member]
Affiliations [Abstract]
Equity interest	50.00%	50.00%
Marina Energy LLC [Member] | LVE Energy Partners, LLC (LVE) [Member] | LVE Energy Partners [Member]
Affiliations [Abstract]
Proceeds from sale of interest in joint venture				57,900
Charge incurred to write-off the remaining interest				$ 800
SJI Midstream, LLC [Member] | PennEast Pipeline Company, LLC (PennEast) [Member]
Affiliations [Abstract]
Equity interest	20.00%	20.00%

AFFILIATIONS AND DISCONTINUED51

AFFILIATIONS AND DISCONTINUED OPERATIONS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Loss before Income Taxes: [Abstract]
Income Tax Benefits									$ 257	$ 312	$ 426
Loss from Discontinued Operations - (Net of tax benefit)	$ (62)	$ (91)	$ (74)	$ (276)	$ (69)	$ (120)	$ (80)	$ (313)	$ (503)	$ (582)	$ (796)
Earnings Per Common Share from Discontinued Operations - Net
Basic and Diluted (in USD per share)									$ (0.01)	$ (0.01)	$ (0.01)
Sand Mining [Member]
Loss before Income Taxes: [Abstract]
Loss before Income Taxes									$ (422)	$ (620)	$ (406)
Fuel Oil [Member]
Loss before Income Taxes: [Abstract]
Loss before Income Taxes									$ (338)	$ (274)	$ (816)

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Tax at Statutory Rate									$ 37,440	$ 35,727	$ 22,181
Increase (Decrease) Resulting from:
State Income Taxes									3,985	1,960	971
ESOP Dividend									(1,298)	(1,232)	(1,176)
Amortization of Investment Tax Credits - Utility									(149)	(211)	(258)
AFUDC									(1,109)	(1,481)	(916)
Investment and Other Tax Credits									(37,503)	(30,661)	(38,179)
Other - Net									(6)	347	(1,637)
Income Taxes: Continuing Operations	$ (1,006)	$ (10,968)	$ (3,279)	$ 16,613	$ 10,415	$ (8,325)	$ (9,510)	$ 11,869	1,360	4,449	(19,014)
Income Taxes: Discontinued Operations									(257)	(312)	(426)
Total Income Tax Expense (Benefit)									1,103	4,137	(19,440)
Current:
Federal									0	(62)	(273)
State									(2,352)	3,052	3,066
Total Current									(2,352)	2,990	2,793
Deferred:
Federal									(4,622)	1,707	(19,978)
State									8,483	(37)	(1,571)
Total Deferred									3,861	1,670	(21,549)
Investment Tax Credit - Utility									(149)	(211)	(258)
Income Taxes: Continuing Operations	(1,006)	$ (10,968)	$ (3,279)	16,613	10,415	$ (8,325)	$ (9,510)	11,869	1,360	4,449	(19,014)
Income Taxes: Discontinued Operations									$ (257)	(312)	(426)
Annual amortization rate of investment tax credits									3.00%
Deferred Tax Assets:
Net Operating Loss Carryforward	195,358				157,174				$ 195,358	157,174
Investment and Other Tax Credits	200,491				154,805				200,491	154,805
Derivatives / Unrealized Gain	5,652				12,554				5,652	12,554
Conservation Incentive Program	0				2,027				0	2,027
Deferred State Tax	24,833				21,548				24,833	21,548
Investment Tax Credit Basis Gross-Up	0				77				0	77
Pension & Other Post Retirement Benefits	29,998				34,892				29,998	34,892
Deferred Revenues	4,924				11,647				4,924	11,647
Provision for Uncollectibles	4,200				6,296				4,200	6,296
Other	6,448				6,734				6,448	6,734
Total Deferred Tax Asset	471,904				407,754				471,904	407,754
Deferred Tax Liabilities:
Book versus Tax Basis of Property	675,521				558,960				675,521	558,960
Deferred Gas Costs - Net	3,998				22,959				3,998	22,959
Environmental Remediation	19,207				12,147				19,207	12,147
Deferred Regulatory Costs	566				6,333				566	6,333
Budget Billing - Customer Accounts	830				1,138				830	1,138
Deferred Pension & Other Post Retirement Benefits	42,216				39,891				42,216	39,891
Conservation Incentive Program	1,132				0				1,132	0
Equity In Loss Of Affiliated Companies	9,111				39,230				9,111	39,230
Other	15,268				13,868				15,268	13,868
Total Deferred Tax Liability	767,849				694,526				767,849	694,526
Current Deferred Tax Asset	0				57,748				0	57,748
Noncurrent Deferred Tax Liability	295,945				344,520				295,945	344,520
Deferred Tax Liability - Net	295,945				286,772				295,945	286,772
Research and development credits	1,400								1,400
Accrued interest and penalties on unrecognized tax benefits	700				700				700	700	600
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1,				$ 552				$ 547	552	547	503
Increase as a result of tax positions taken in prior years									7	5	44
Decrease due to a lapse in the statute of limitations									0	0	0
Settlements									0	0	0
Balance at December 31,	559				$ 552				559	$ 552	$ 547
Federal [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	527,407								527,407
Tax credit carryforwards	197,766								197,766
Alternative minimum tax credits	1,200								1,200
Federal [Member] | 2030 [Member]
Deferred Tax Liabilities:
Tax credit carryforwards	11,628								11,628
Federal [Member] | 2031 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	163,880								163,880
Tax credit carryforwards	26,613								26,613
Federal [Member] | 2032 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	43,724								43,724
Tax credit carryforwards	32,071								32,071
Federal [Member] | 2033 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	68,696								68,696
Tax credit carryforwards	46,179								46,179
Federal [Member] | 2034 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	117,325								117,325
Tax credit carryforwards	38,727								38,727
Federal [Member] | 2035 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	133,782								133,782
Tax credit carryforwards	42,548								42,548
State and Local Jurisdiction [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	150,469								150,469
State and Local Jurisdiction [Member] | 2031 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	45,866								45,866
State and Local Jurisdiction [Member] | 2032 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	19,356								19,356
State and Local Jurisdiction [Member] | 2033 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	34,940								34,940
State and Local Jurisdiction [Member] | 2034 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	28,622								28,622
State and Local Jurisdiction [Member] | 2035 [Member]
Deferred Tax Liabilities:
Operating loss carryforwards	$ 21,685								$ 21,685

PREFERRED STOCK (Details)

PREFERRED STOCK (Details)	Dec. 31, 2015shares
Equity [Abstract]
Preferred Stock, shares authorized	2,500,000

COMMON STOCK (Details)

COMMON STOCK (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning of Year	68,334,860	65,430,084	63,306,524
New Issues During Year:
Dividend Reinvestment Plan	2,604,424	2,881,556	1,966,834
Stock-Based Compensation Plan	26,338	23,220	156,726
End of Year	70,965,622	68,334,860	65,430,084
Par value of common stock (in USD per share)	$ 1.25	$ 1.25
Net excess over par value recorded in premium on common stock (in USD)	$ 61,100
Incremental shares included in diluted earnings per share (in shares)	195,139	150,062	115,520
Dividend per share (in USD per share)	$ 1.02	$ 0.96	$ 0.9
Equity capital raised through Dividend Reinvestment Plan (in USD)	$ 63,192	$ 80,680	$ 54,028

FINANCIAL INSTRUMENTS (Details)

FINANCIAL INSTRUMENTS (Details)	1 Months Ended	12 Months Ended
	Jun. 30, 2015USD ($)term	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2011
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity investment impairments			$ 0	$ 0
Investment in Affiliate		$ 16,983,000	68,351,000
Atlantic City Note Receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Amount of advance repaid		100,000
Term of loans	6 months
Amount of advance	$ 10,000,000
Interest rate of advance	1.00%
Number of additional terms | term	2
Extension term	3 months
Energenic US LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Contract term					20 years
Loss from equity method investment, before tax		7,500,000
Equity investment impairments		7,700,000
Investment in Affiliate		1,700,000
Notes receivable due from Affiliate		$ 13,700,000
Marina Energy LLC [Member] | Energenic US LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity interest		50.00%
ACB Energy Partners, LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Debt service reserve		$ 1,700,000
South Jersey Gas Company [Member] | Minimum [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Term of loans		5 years
South Jersey Gas Company [Member] | Maximum [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Term of loans		10 years
Level 1 [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Margin accounts with selected counterparties to support risk management activities		$ 43,700,000	63,700,000
Level 1 [Member] | Marina Energy LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted investments held in escrow		3,400,000	1,700,000
Level 2 [Member] | South Jersey Gas Company [Member] | Financing Receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Long-term receivables, net of unamortized discount		12,900,000	15,000,000
Imputed interest on long term receivables		$ 1,300,000	$ 1,300,000

FINANCIAL INSTRUMENTS - CREDIT

FINANCIAL INSTRUMENTS - CREDIT RISK (Details) - Derivatives Energy Related Assets [Member] - Supplier Concentration Risk [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Concentration Risk [Line Items]
Amount of derivatives - energy related assets with single retail counterparty	$ 11.7
Percentage of derivatives - energy related assets with a single retail counterparty (in hundredths)	11.80%

FINANCIAL INSTRUMENTS - FINANCE

FINANCIAL INSTRUMENTS - FINANCE OBLIGATION AND FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2014	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Finance obligation to ACB Energy Partners LLC		$ 19,659	$ 0
Carrying amount of long-term debt	[1]	1,009,400	1,035,848
Level 2 [Member]
Schedule of Equity Method Investments [Line Items]
Estimated fair value of long-term debt		1,058,500	1,079,000
Carrying amount of long-term debt		1,009,400	$ 1,035,800
Marina Energy LLC [Member] | Energenic US LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity interest			50.00%
Other construction costs		$ 23,700
[1]	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2016, $29,454; 2017, $172,558; 2018,$40,667; 2019,$260,783; and 2020, $74,476.

SEGMENTS OF BUSINESS (Details)

SEGMENTS OF BUSINESS (Details) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2015USD ($)investment	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2015USD ($)investment	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Segment Reporting Information [Line Items]
Operating Revenues		$ 257,844	$ 141,062	$ 177,710	$ 382,952	$ 281,097	$ 122,427	$ 133,271	$ 350,201	$ 959,568	$ 886,996	$ 731,421
Operating Income (Loss)										156,894	127,603	69,636
Depreciation and Amortization										91,042	78,511	64,890
Interest Charges										31,622	29,560	18,825
Income Taxes		(1,006)	$ (10,968)	$ (3,279)	$ 16,613	10,415	$ (8,325)	$ (9,510)	$ 11,869	1,360	4,449	(19,014)
Property Additions										361,994	339,469	328,504
Identifiable Assets		$ 3,480,900				3,349,425				3,480,900	3,349,425
Marina Energy LLC [Member] | Energenic US LLC [Member]
Segment Reporting Information [Line Items]
Noncash or Part Noncash Acquisition, Fixed Assets Acquired										$ 40,900
Number of investments owned | investment		8								8
Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating Revenues										$ 1,006,642	926,518	772,551
Interest Charges										40,523	36,036	23,731
Operating Segments [Member] | Gas Utility Operations [Member]
Segment Reporting Information [Line Items]
Operating Revenues										534,290	501,875	446,480
Operating Income (Loss)										119,585	113,690	105,822
Depreciation and Amortization										58,668	52,155	48,261
Interest Charges										19,906	17,872	12,550
Income Taxes										36,945	34,895	34,833
Property Additions										218,260	201,737	173,099
Identifiable Assets		$ 2,288,204				2,185,672				2,288,204	2,185,672
Operating Segments [Member] | Energy Group [Member]
Segment Reporting Information [Line Items]
Operating Revenues										366,345	327,822	237,511
Operating Income (Loss)										32,848	9,506	(37,540)
Depreciation and Amortization										596	251	299
Interest Charges										626	638	697
Income Taxes										13,858	5,419	(14,676)
Property Additions										2,435	1,439	752
Identifiable Assets		342,299				442,874				342,299	442,874
Operating Segments [Member] | Energy Group [Member] | Wholesale Energy Operations [Member]
Segment Reporting Information [Line Items]
Operating Revenues										129,098	77,048	831
Operating Income (Loss)										35,024	9,493	(37,720)
Depreciation and Amortization										435	168	206
Interest Charges										441	371	417
Income Taxes										14,410	4,822	(15,070)
Property Additions										382	18	50
Identifiable Assets		231,660				366,119				231,660	366,119
Operating Segments [Member] | Energy Group [Member] | Retail Gas and Other Operations [Member]
Segment Reporting Information [Line Items]
Operating Revenues										87,198	127,001	107,748
Operating Income (Loss)										(3,218)	479	278
Depreciation and Amortization										161	83	93
Interest Charges										185	267	280
Income Taxes										(978)	787	434
Property Additions										2,053	1,421	702
Identifiable Assets		55,111				53,073				55,111	53,073
Operating Segments [Member] | Energy Group [Member] | Retail Electric Operations [Member]
Segment Reporting Information [Line Items]
Operating Revenues										150,049	123,773	128,932
Operating Income (Loss)										1,042	(466)	(98)
Income Taxes										426	(190)	(40)
Identifiable Assets		55,528				23,682				55,528	23,682
Operating Segments [Member] | Energy Services [Member]
Segment Reporting Information [Line Items]
Operating Revenues										74,851	66,647	57,274
Operating Income (Loss)										2,495	2,922	984
Depreciation and Amortization										30,558	25,289	15,453
Income Taxes										(49,039)	(36,181)	(39,518)
Property Additions										139,397	132,298	151,592
Identifiable Assets		796,121				679,042				796,121	679,042
Operating Segments [Member] | Energy Services [Member] | On-site Energy Production [Member]
Segment Reporting Information [Line Items]
Operating Revenues										63,665	56,129	43,551
Operating Income (Loss)										2,027	2,560	(2,011)
Depreciation and Amortization										30,242	25,020	15,192
Interest Charges										8,169	8,723	4,480
Income Taxes										(49,225)	(36,404)	(40,755)
Property Additions	[1]									139,018	132,214	151,592
Identifiable Assets		791,236				675,937				791,236	675,937
Operating Segments [Member] | Energy Services [Member] | Appliance Service Operations [Member]
Segment Reporting Information [Line Items]
Operating Revenues										11,186	10,518	13,723
Operating Income (Loss)										468	362	2,995
Depreciation and Amortization										316	269	261
Income Taxes										186	223	1,237
Property Additions										379	84	0
Identifiable Assets		4,885				3,105				4,885	3,105
Operating Segments [Member] | Corporate and Services [Member]
Segment Reporting Information [Line Items]
Operating Revenues										31,156	30,174	31,286
Operating Income (Loss)										1,966	1,485	370
Depreciation and Amortization										1,220	816	877
Interest Charges										11,822	8,803	6,004
Income Taxes										(404)	316	347
Property Additions										1,902	3,995	3,061
Identifiable Assets		653,659				527,691				653,659	527,691
Discontinued Operations [Member]
Segment Reporting Information [Line Items]
Identifiable Assets		1,545				1,758				1,545	1,758
Intersegment [Member]
Segment Reporting Information [Line Items]
Operating Revenues										(47,074)	(39,522)	(41,130)
Interest Charges										(8,901)	(6,476)	$ (4,906)
Identifiable Assets		$ (600,928)				$ (487,612)				$ (600,928)	$ (487,612)
[1]	The property additions for On-Site Energy Production do not include the approximately $40.9 million of Property, Plant and Equipment obtained through the acquisition of eight Energenic projects as discussed in Note 3.

LEASES - Operating Lease (Detai

LEASES - Operating Lease (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Operating Leases, Future Minimum Payments Receivable [Abstract]
2,016	$ 5,396
2,017	5,396
2,018	5,396
2,019	5,396
2,020	5,396
Thereafter	34,626
Total minimum future rentals	61,606
Thermal Energy Generating Property and Equipment [Member]
Property Subject to or Available for Operating Lease, Net [Abstract]
Property and equipment under operating lease	78,200	$ 79,900
Accumulated depreciation of property and equipment under operating lease	$ 28,500	$ 25,400

LEASES - Capital Lease (Details

LEASES - Capital Lease (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Capital Leased Assets [Line Items]
Useful life	50 years
Equipment and Facilities [Member]
Capital Leased Assets [Line Items]
Interest rate	6.80%
Carrying cost of leased assets	$ 4,100
Capital Leases, Future Minimum Payments, Net Present Value [Abstract]
2,016	1,282
2,017	1,282
2,018	1,282
2,019	1,282
2,020	1,282
Thereafter	8,657
Total minimum future rentals	15,067
Less: Interest portion	(4,710)
Present value of future minimum lease payments	$ 10,357
Equipment and Facilities [Member] | Minimum [Member]
Capital Leased Assets [Line Items]
Useful life	7 years
Equipment and Facilities [Member] | Maximum [Member]
Capital Leased Assets [Line Items]
Useful life	39 years

RATES AND REGULATORY ACTIONS (D

RATES AND REGULATORY ACTIONS (Details) $ in Thousands	1 Months Ended													12 Months Ended		15 Months Ended	61 Months Ended	288 Months Ended
	Aug. 31, 2015USD ($)	Sep. 30, 2014USD ($)	Aug. 31, 2014USD ($)	Jan. 31, 2014USD ($)	Sep. 30, 2013USD ($)	Jun. 30, 2013USD ($)	Feb. 28, 2013USD ($)	Jan. 31, 2013USD ($)	Jul. 31, 2012USD ($)	Sep. 30, 2010USD ($)	Jan. 31, 2010	Jan. 31, 2009USD ($)	Oct. 31, 2006	Dec. 31, 2015USD ($)sitecustomer	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)sitecustomer	Sep. 30, 2014USD ($)	Dec. 31, 2015USD ($)sitecustomer	Sep. 30, 2015USD ($)	Jul. 31, 2015USD ($)	Apr. 30, 2015USD ($)	Jan. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jul. 31, 2014USD ($)	Jun. 30, 2014USD ($)	May. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Oct. 31, 2013USD ($)	Jul. 31, 2013USD ($)	May. 31, 2013USD ($)	Jun. 30, 2012USD ($)	May. 31, 2012USD ($)
Schedule of Capitalization [Line Items]
Approved base rate increase		$ 20,000								$ 42,100
Rate of return on base rate		7.10%								8.21%
Return on common equity		9.75%								10.30%
Annual depreciation expense reduction attributable to petition										$ 1,200
Investments to be rolled to base rate																											$ 22,500	$ 95,000
Composite depreciate rate																2.10%	2.40%
Term of AIRP							4 years		5 years
Amount of AIRP							$ 141,200		$ 250,000
Annual investment amount of AIRP							$ 35,300
Investment amount of SHARP			$ 103,500		$ 280,000										$ 36,600
Term of SHARP			3 years		7 years
Number of sites for environmental cleanup (in sites) | site														12		12		12
Regulatory assets														$ 323,434		$ 323,434		$ 323,434					$ 357,160
Number of customers purchasing energy commodity from another entity | customer														35,400		35,400		35,400
Amount of incremental expenses requested for deferral						$ 700
Environmental restoration costs expended net [Member]
Schedule of Capitalization [Line Items]
Regulatory assets														$ 42,032		$ 42,032		$ 42,032					29,540
Deferred pipeline integrity costs [Member]
Schedule of Capitalization [Line Items]
Regulatory assets														$ 2,700		$ 2,700		$ 2,700					3,400
Conservation Incentive Program [Member]
Schedule of Capitalization [Line Items]
Approved base rate increase										16,600
Amount of increase (decrease) in regulatory costs requested for recovery not yet approved															(11,300)											$ (21,800)				$ (17,800)
Amount of increase (decrease) in regulatory costs approved					$ 15,500
Regulatory costs, period													3 years
Extension period											1 year
Conservation Incentive Program [Member] | Non-weather Member]
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs requested for recovery not yet approved															(8,800)											4,200				(2,300)
Conservation Incentive Program [Member] | Weather [Member]
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs requested for recovery not yet approved															(2,500)											(26,000)				(15,500)
Capital Investment Recovery Tracker [Member]
Schedule of Capitalization [Line Items]
Approved base rate increase										6,800
Incremental Revenue [Member]
Schedule of Capitalization [Line Items]
Approved base rate increase										$ 18,700
Accelerated Infrastructure Replacement Program [Member]
Schedule of Capitalization [Line Items]
Approved base rate increase		$ 7,500
Investments to be rolled to base rate		69,900															$ 69,900
Basic Gas Supply Service [Member]
Schedule of Capitalization [Line Items]
Proceeds from (repayments for) regulatory action				$ (11,200)				$ (9,400)
Amount of increase (decrease) in regulatory costs requested for recovery not yet approved															(28,400)											$ 27,000				(600)
Amount of increase (decrease) in regulatory costs approved		27,000			(600)												27,000		$ (28,400)
Percent of increase (decrease) in regulatory costs not yet approved																										9.30%
Storm Hardening and Reliability Program [Member]
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs requested for recovery not yet approved																					$ 4,000
Amount of increase (decrease) in regulatory costs approved																			4,000
Energy Efficiency Tracker [Member]
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs requested for recovery not yet approved															(7,600)							$ 56,000				$ 1,400				$ 2,200	$ 5,800	$ 3,100
Amount of increase (decrease) in regulatory costs approved	$ 2,600	2,200				24,000											2,200												$ 2,100
Regulatory costs, period												2 years
Extension period	2 years
Amount of regulatory costs available for recovery	$ 36,300											$ 17,000
Societal Benefits Clause [Member]
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs requested for recovery not yet approved																				$ (5,000)				$ (25,700)					$ (6,400)
Remediation Adjustment Clause [Member]
Schedule of Capitalization [Line Items]
Number of sites for environmental cleanup (in sites) | site														12		12		12
Amortization period														7 years
Regulated costs recovered																		$ 110,500
Remediation Adjustment Clause [Member] | Environmental restoration costs expended net [Member]
Schedule of Capitalization [Line Items]
Regulatory assets														$ 42,000		$ 42,000		$ 42,000					$ 29,500
New Jersey Clean Energy Program [Member]
Schedule of Capitalization [Line Items]
Amount of statewide funding approved						345,000									345,000										$ 345,000
Regulatory costs entity is expensing						14,500									14,600										14,500
Universal Service Fund [Member]
Schedule of Capitalization [Line Items]
Amount of increase (decrease) in regulatory costs approved		7,900			5,800												7,900		5,200
Amount of statewide funding approved		71,800			54,400												71,800		46,400
Amount of statewide costs proposed						(29,400)									(46,400)										19,900
Amount of proposed impact of annual costs						$ (3,700)									$ (3,400)				$ (3,400)						$ 2,600
Amount of increase (decrease) in annual impact approved		$ 2,600			$ (3,400)												$ 2,600

REGULATORY ASSETS & REGULATOR62

REGULATORY ASSETS & REGULATORY LIABILITIES (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)siteregulatory_assets	Dec. 31, 2006USD ($)	Dec. 31, 2014USD ($)
Regulatory Assets [Line Items]
Total regulatory assets	$ 323,434		$ 357,160
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) | regulatory_assets	2
Number of sites where SJG or their predecessors previously operated gas manufacturing plants (in sites) | site	12
Environmental Restoration Costs [Member]
Regulatory Assets [Line Items]
Regulatory costs, original recovery period of expenditures	7 years
Environmental Remediation Costs: Expended - Net [Member]
Regulatory Assets [Line Items]
Total regulatory assets	$ 42,032		29,540
Environmental Restoration Costs Liability for Future Expenditures [Member]
Regulatory Assets [Line Items]
Total regulatory assets	123,194		124,308
Deferred Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets	42,430		31,584
Deferred Pension and Other Postretirement Benefit Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets	79,779		99,040
Regulatory asset, amount of increase		$ 37,100
Deferred Gas Costs - Net [Member]
Regulatory Assets [Line Items]
Total regulatory assets	2,701		32,202
Conservation Incentive Program Receivable [Member]
Regulatory Assets [Line Items]
Total regulatory assets	2,624		0
Societal Benefit Costs Receivable [Member]
Regulatory Assets [Line Items]
Total regulatory assets	0		385
Deferred Interest Rate Contracts [Member]
Regulatory Assets [Line Items]
Total regulatory assets	7,631		7,325
Energy Efficiency Tracker [Member]
Regulatory Assets [Line Items]
Total regulatory assets	496		11,247
Pipeline Supplier Service Charges [Member]
Regulatory Assets [Line Items]
Total regulatory assets	3,776		5,441
Pipeline Integrity Cost [Member]
Regulatory Assets [Line Items]
Total regulatory assets	4,596		3,431
AFUDC - Equity Related Deferrals [Member]
Regulatory Assets [Line Items]
Total regulatory assets	11,423		10,781
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Total regulatory assets	2,752		$ 1,876
Allowance for Funds Used Under Construction, Equity Related Deferrals, Settlement [Member]
Regulatory Assets [Line Items]
Total regulatory assets	$ 2,300
Regulatory costs, original recovery period of expenditures	3 years

REGULATORY ASSETS & REGULATOR63

REGULATORY ASSETS & REGULATORY LIABILITIES - ADDITIONAL DETAILS (Details) - USD ($) $ in Thousands	1 Months Ended
	Sep. 30, 2014	Dec. 31, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Total regulatory liabilities		$ 42,841	$ 41,899
Excess Plant Removal Costs [Member]
Regulatory Liabilities [Line Items]
Total regulatory liabilities		32,644	35,940
Annual amortization reflected in depreciation expense	$ 1,100
Societal Benefit Costs Payable [Member]
Regulatory Liabilities [Line Items]
Total regulatory liabilities		10,197	1,025
Conservation Incentive Program - Payable [Member]
Regulatory Liabilities [Line Items]
Total regulatory liabilities		0	4,700
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Total regulatory liabilities		$ 0	$ 234

PENSION AND OTHER POSTRETIREM64

PENSION AND OTHER POSTRETIREMENT BENEFITS - NET PERIODIC BENEFIT COST (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Compensation and Retirement Disclosure [Abstract]
Defined Benefit Plan, Estimated Percentage of Employees to be Entitled to Annuity Payments Upon Retirement	43.00%
Pension Plan [Member]
Net periodic benefit cost [Abstract]
Service Cost	$ 5,337	$ 4,510	$ 5,421
Interest Cost	11,168	10,735	9,439
Expected Return on Plan Assets	(14,789)	(13,491)	(11,914)
Amortizations:
Prior Service Cost (Credits)	212	175	251
Actuarial Loss	10,608	5,716	9,006
Net Periodic Benefit Cost	12,536	7,645	12,203
Capitalized Benefit Costs	(4,805)	(3,047)	(5,002)
Deferred Benefit Costs	(1,007)	0	0
Total Net Periodic Benefit Expense	6,724	4,598	7,201
Other Postretirement Benefits [Member]
Net periodic benefit cost [Abstract]
Service Cost	1,116	891	1,139
Interest Cost	2,973	2,852	2,730
Expected Return on Plan Assets	(2,993)	(2,603)	(2,378)
Amortizations:
Prior Service Cost (Credits)	608	152	(283)
Actuarial Loss	1,342	974	1,738
Net Periodic Benefit Cost	3,046	2,266	2,946
Capitalized Benefit Costs	(1,043)	(722)	(1,172)
Deferred Benefit Costs	(256)	0	0
Total Net Periodic Benefit Expense	$ 1,747	$ 1,544	$ 1,774

PENSION AND OTHER POSTRETIREM65

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, 2015	Dec. 31, 2014
Pension Benefits [Member]
Regulatory Assets
Beginning Balance	$ 71,177	$ 42,632
Amounts Arising during the Period: Net Actuarial (Loss) Gain	(463)	31,075
Amounts Arising during the Period: Prior Service Cost (Credit)	0	486
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(6,079)	(2,841)
Amounts Amortized to Net Periodic Costs: Prior Service (Cost) Credit	(203)	(175)
Ending Balance	64,432	71,177
Accumulated Other Comprehensive Loss (pre-tax)
Beginning Balance	39,468	27,574
Amounts Arising during the Period: Net Actuarial (Loss) Gain	59	14,698
Amounts Arising during the Period: Prior Service Cost (Credit)	0	14
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(4,452)	(2,819)
Amounts Amortized to Net Periodic Costs: Prior Service (Cost) Credit	(9)	1
Ending Balance	35,066	39,468
Other Postretirement Benefits [Member]
Regulatory Assets
Beginning Balance	27,863	16,652
Amounts Arising during the Period: Net Actuarial (Loss) Gain	(3,155)	7,826
Amounts Arising during the Period: Prior Service Cost (Credit)	(499)	4,146
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(1,107)	(628)
Amounts Amortized to Net Periodic Costs: Prior Service (Cost) Credit	(7,755)	(133)
Ending Balance	15,347	27,863
Accumulated Other Comprehensive Loss (pre-tax)
Beginning Balance	6,755	3,710
Amounts Arising during the Period: Net Actuarial (Loss) Gain	(2,285)	2,269
Amounts Arising during the Period: Prior Service Cost (Credit)	(106)	981
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	(221)	(187)
Amounts Amortized to Net Periodic Costs: Prior Service (Cost) Credit	(2,081)	(18)
Ending Balance	$ 2,062	$ 6,755

PENSION AND OTHER POSTRETIREM66

PENSION AND OTHER POSTRETIREMENT BENEFITS - ESTIMATED COSTS THAT WILL BE AMORTIZED (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior Service Cost/(Credit) amortized from Regulatory Assets into net periodic benefit costs	$ 203
Net Actuarial Loss amortized from Regulatory Assets into net periodic benefit costs	5,488
Prior Service Cost/(Credit) amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs	9
Net Actuarial Loss amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs	3,747
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior Service Cost/(Credit) amortized from Regulatory Assets into net periodic benefit costs	(257)
Net Actuarial Loss amortized from Regulatory Assets into net periodic benefit costs	998
Prior Service Cost/(Credit) amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs	(88)
Net Actuarial Loss amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs	$ 179

PENSION AND OTHER POSTRETIREM67

PENSION AND OTHER POSTRETIREMENT BENEFITS - RECONCILIATIONS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	$ (2,261)	$ (1,550)
Noncurrent Liabilities	(76,068)	(115,373)
Pension Benefits [Member]
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	265,434	216,395
Service Cost	5,337	4,510	$ 5,421
Interest Cost	11,168	10,735	9,439
Actuarial (Gain) Loss	(17,349)	42,746
Retiree Contributions	0	0
Plan Amendments	0	550
Benefits Paid	(10,395)	(9,502)
Benefit Obligation at End of Year	254,195	265,434	216,395
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	180,523	178,093
Actual Return on Plan Assets	(2,321)	10,397
Employer Contributions	17,017	1,535
Retiree Contributions	0	0
Benefits Paid	(10,395)	(9,502)
Fair Value of Plan Assets at End of Year	184,824	180,523	178,093
Funded Status at End of Year	(69,371)	(84,911)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	(2,261)	(1,550)
Noncurrent Liabilities	(66,906)	(83,304)
Net Amount Recognized at End of Year	(69,167)	(84,854)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	741	944
Net Actuarial Loss	63,691	70,233
Amount Recognized in Regulatory Assets	64,432	71,177	42,632
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	77	86
Net Actuarial Loss	34,989	39,382
Amount Recognized in Accumulated Other Comprehensive Loss	35,066	39,468	27,574
Projected benefit obligation	207,700	219,700
Accumulated benefit obligation	191,900	201,000
Pension Benefits [Member] | Amounts Related to Unconsolidated Affiliate [Member]
Change in Plan Assets:
Funded Status at End of Year	204	57
Pension Benefits [Member] | Accrued Net Benefit Cost at End of Year [Member]
Change in Plan Assets:
Funded Status at End of Year	(69,167)	(84,854)
Other Postretirement Benefits [Member]
Change in Benefit Obligations:
Benefit Obligation at Beginning of Year	75,592	62,355
Service Cost	1,116	891	1,139
Interest Cost	2,973	2,852	2,730
Actuarial (Gain) Loss	(8,591)	8,151
Retiree Contributions	700	488
Plan Amendments	(9,899)	5,143
Benefits Paid	(4,461)	(4,288)
Benefit Obligation at End of Year	57,430	75,592	62,355
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	43,222	41,653
Actual Return on Plan Assets	(423)	596
Employer Contributions	8,721	4,773
Retiree Contributions	700	488
Benefits Paid	(4,461)	(4,288)
Fair Value of Plan Assets at End of Year	47,759	43,222	41,653
Funded Status at End of Year	(9,671)	(32,370)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	0	0
Noncurrent Liabilities	(9,162)	(32,069)
Net Amount Recognized at End of Year	(9,162)	(32,069)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	(3,289)	4,965
Net Actuarial Loss	18,636	22,898
Amount Recognized in Regulatory Assets	15,347	27,863	16,652
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	(1,074)	1,113
Net Actuarial Loss	3,136	5,642
Amount Recognized in Accumulated Other Comprehensive Loss	2,062	6,755	3,710
Other Postretirement Benefits [Member] | Amounts Related to Unconsolidated Affiliate [Member]
Change in Plan Assets:
Funded Status at End of Year	509	301
Other Postretirement Benefits [Member] | Accrued Net Benefit Cost at End of Year [Member]
Change in Plan Assets:
Funded Status at End of Year	(9,162)	(32,069)
Supplemental Employee Retirement Plan [Member]
Change in Plan Assets:
Employer Contributions	2,000	1,500	$ 1,300
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Projected benefit obligation	46,500	45,700
Accumulated benefit obligation	$ 45,000	$ 44,500

PENSION AND OTHER POSTRETIREM68

PENSION AND OTHER POSTRETIREMENT BENEFITS - WEIGHTED-AVERAGE ASSUMPTIONS (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Pension Benefits [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount Rate	4.83%	4.25%
Rate of Compensation Increase	3.50%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount Rate	4.25%	5.09%	4.26%
Expected Long-Term Return on Plan Assets	7.75%	7.75%	7.50%
Rate of Compensation Increase	3.50%	3.50%	3.25%
Other Postretirement Benefits [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount Rate	4.73%	4.20%
Rate of Compensation Increase	3.50%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount Rate	4.20%	4.91%	4.14%
Expected Long-Term Return on Plan Assets	6.25%	6.25%	6.60%
Rate of Compensation Increase	3.50%	3.50%	3.25%

PENSION AND OTHER POSTRETIREM69

PENSION AND OTHER POSTRETIREMENT BENEFITS - ASSUMED HEALTH CARE COST TREND RATES (Details) - Other Postretirement Benefits [Member]	12 Months Ended
	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Medical Care and Drug Cost Trend Rate Assumed for Next Year	7.00%
Dental Care Cost Trend Rate Assumed for Next Year	4.75%
Rate to which Cost Trend Rates are Assumed to Decline (the Ultimate Trend Rate)	4.75%
Year that the Rate Reaches the Ultimate Trend Rate	2,023

PENSION AND OTHER POSTRETIREM70

PENSION AND OTHER POSTRETIREMENT BENEFITS - EFFECTS OF ONE PERCENTAGE POINT CHANGE IN ASSUMED HEALTH CARE COST (Details) - Other Postretirement Benefits [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
1 - Percentage Point Increase, Effect on the Total of Service and Interest Cost	$ 199
1 - Percentage Point Decrease, Effect on the Total of Service and Interest Cost	$ (160)

PENSION AND OTHER POSTRETIREM71

PENSION AND OTHER POSTRETIREMENT BENEFITS - PLAN ASSETS (Details) - Pension Benefits [Member]	12 Months Ended
	Dec. 31, 2015USD ($)
Defined Benefit Plan Disclosure [Line Items]
Required capitalization for plan asset allocation (less than)	$ 250,000,000
Required capitalization for plan asset allocation, small cap (as low as)	$ 50,000,000
U.S. equity securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	28.00%
Target allocation percentage of assets, equity securities, range maximum	48.00%
International equity securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	13.00%
Target allocation percentage of assets, equity securities, range maximum	25.00%
Fixed income securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	32.00%
Target allocation percentage of assets, equity securities, range maximum	42.00%
Other Investments [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation percentage of assets, equity securities, range minimum	0.00%
Target allocation percentage of assets, equity securities, range maximum	14.00%

PENSION AND OTHER POSTRETIREM72

PENSION AND OTHER POSTRETIREMENT BENEFITS - FAIR VALUE OF PLAN ASSETS (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		$ 180,523		$ 178,093
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		180,523		178,093
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		$ 184,824		180,523
Pension Benefits [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Fund Valuations Lag Period		90 days
Pension Benefits [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Fund Valuations Lag Period		120 days
Pension Benefits [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		$ 21,709		21,709
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		21,709
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		19,702		21,709
Pension Benefits [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		132,479		132,479
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		132,479
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		138,176		132,479
Pension Benefits [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		26,335		25,263
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		26,335		25,263
Actual return on plan assets:
Relating to assets still held at the reporting date		459		1,386
Relating to assets sold during the period		454		338
Purchases, Sales and Settlements		(302)		(652)
Fair Value of Plan Assets at End of Year		26,946		26,335
Pension Benefits [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		35
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		35
Pension Benefits [Member] | Cash [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		35
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		35
Pension Benefits [Member] | Cash [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits [Member] | Cash [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0
Pension Benefits [Member] | Common / Collective Trust Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	692		692
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	692
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	858		692
Pension Benefits [Member] | Common / Collective Trust Funds [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	0		0
Pension Benefits [Member] | Common / Collective Trust Funds [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	692		692
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	692
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	858		692
Pension Benefits [Member] | Common / Collective Trust Funds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	0		0
Pension Benefits [Member] | STIF-Type Instrument [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[2]	1,252		1,252
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[2]	1,252
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[2]	1,360		1,252
Pension Benefits [Member] | STIF-Type Instrument [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[2]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[2]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[2]	0		0
Pension Benefits [Member] | STIF-Type Instrument [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[2]	1,252		1,252
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[2]	1,252
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[2]	1,360		1,252
Pension Benefits [Member] | STIF-Type Instrument [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[2]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[2]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[2]	0		0
Pension Benefits [Member] | Common/Collective Trust Funds - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	51,197		51,197
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	51,197
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	52,058		51,197
Pension Benefits [Member] | Common/Collective Trust Funds - U.S. [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	0		0
Pension Benefits [Member] | Common/Collective Trust Funds - U.S. [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	51,197		51,197
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	51,197
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	52,058		51,197
Pension Benefits [Member] | Common/Collective Trust Funds - U.S. [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	0		0
Pension Benefits [Member] | U.S. Large-Cap [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	12,961		12,961
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	12,961
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	14,305		12,961
Pension Benefits [Member] | U.S. Large-Cap [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	12,961		12,961
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	12,961
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	14,305		12,961
Pension Benefits [Member] | U.S. Large-Cap [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	0		0
Pension Benefits [Member] | U.S. Large-Cap [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	0		0
Pension Benefits [Member] | U.S. Mid-Cap [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	5,147		5,147
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	5,147
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	3,407		5,147
Pension Benefits [Member] | U.S. Mid-Cap [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	5,147		5,147
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	5,147
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	3,407		5,147
Pension Benefits [Member] | U.S. Mid-Cap [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	0		0
Pension Benefits [Member] | U.S. Mid-Cap [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	0		0
Pension Benefits [Member] | U.S. Small-Cap [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	232		232
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	232
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	260		232
Pension Benefits [Member] | U.S. Small-Cap [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	232		232
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	232
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	260		232
Pension Benefits [Member] | U.S. Small-Cap [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	0		0
Pension Benefits [Member] | U.S. Small-Cap [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	0		0
Pension Benefits [Member] | International equity securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	3,369		3,369
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	3,369
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	1,695		3,369
Pension Benefits [Member] | International equity securities [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	3,369		3,369
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	3,369
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	1,695		3,369
Pension Benefits [Member] | International equity securities [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	0		0
Pension Benefits [Member] | International equity securities [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[3]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[3]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[3]	0		0
Pension Benefits [Member] | Common/Collective Trust Funds - International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	30,963		30,963
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	30,963
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	33,236		30,963
Pension Benefits [Member] | Common/Collective Trust Funds - International [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	0		0
Pension Benefits [Member] | Common/Collective Trust Funds - International [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	30,963		30,963
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	30,963
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	33,236		30,963
Pension Benefits [Member] | Common/Collective Trust Funds - International [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	0		0
Pension Benefits [Member] | Common/Collective Trust Funds - Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	48,375		48,375
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	48,375
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	50,664		48,375
Pension Benefits [Member] | Common/Collective Trust Funds - Bonds [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	0		0
Pension Benefits [Member] | Common/Collective Trust Funds - Bonds [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	48,375		48,375
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	48,375
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	50,664		48,375
Pension Benefits [Member] | Common/Collective Trust Funds - Bonds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[1]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[1]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[1]	0		0
Pension Benefits [Member] | Guaranteed Insurance Contract [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[4]	10,912		10,912
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[4]	10,912
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[4]	9,960		10,912
Pension Benefits [Member] | Guaranteed Insurance Contract [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[4]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[4]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[4]	0		0
Pension Benefits [Member] | Guaranteed Insurance Contract [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[4]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[4]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[4]	0		0
Pension Benefits [Member] | Guaranteed Insurance Contract [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		10,912	[4]	11,322
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		10,912	[4]	11,322
Actual return on plan assets:
Relating to assets still held at the reporting date		(106)		498
Relating to assets sold during the period		25		13
Purchases, Sales and Settlements		(871)		(921)
Fair Value of Plan Assets at End of Year	[4]	9,960		10,912
Pension Benefits [Member] | Hedge Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[5]	4,331		4,331
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[5]	4,331
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[5]	4,159		4,331
Pension Benefits [Member] | Hedge Funds [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[5]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[5]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[5]	0		0
Pension Benefits [Member] | Hedge Funds [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[5]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[5]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[5]	0		0
Pension Benefits [Member] | Hedge Funds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		4,331	[5]	4,154
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		4,331	[5]	4,154
Actual return on plan assets:
Relating to assets still held at the reporting date		(172)		177
Relating to assets sold during the period		0		0
Purchases, Sales and Settlements		0		0
Fair Value of Plan Assets at End of Year	[5]	4,159		4,331
Pension Benefits [Member] | Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[6]	3,616		3,616
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[6]	3,616
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[6]	4,312		3,616
Pension Benefits [Member] | Private Equity Funds [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[6]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[6]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[6]	0		0
Pension Benefits [Member] | Private Equity Funds [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[6]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[6]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[6]	0		0
Pension Benefits [Member] | Private Equity Funds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		3,616	[6]	3,046
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		3,616	[6]	3,046
Actual return on plan assets:
Relating to assets still held at the reporting date		(302)		(24)
Relating to assets sold during the period		429		325
Purchases, Sales and Settlements		569		269
Fair Value of Plan Assets at End of Year	[6]	4,312		3,616
Pension Benefits [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[7]	7,476		7,476
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[7]	7,476
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[7]	8,515		7,476
Pension Benefits [Member] | Real Estate [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[7]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[7]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[7]	0		0
Pension Benefits [Member] | Real Estate [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[7]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[7]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[7]	0		0
Pension Benefits [Member] | Real Estate [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		7,476	[7]	6,741
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		7,476	[7]	6,741
Actual return on plan assets:
Relating to assets still held at the reporting date		1,039		735
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]	8,515		7,476
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		43,222		41,653
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		43,222		41,653
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		47,759		43,222
Other Postretirement Benefits [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		9,799		9,799
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		9,799
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		3,911		9,799
Other Postretirement Benefits [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		33,423		33,423
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		33,423
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		43,848		33,423
Other Postretirement Benefits [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0		0
Other Postretirement Benefits [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	153		153
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	153
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		26		153	[8]
Other Postretirement Benefits [Member] | Cash [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		153		153
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		153
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		26		153
Other Postretirement Benefits [Member] | Cash [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0		0
Other Postretirement Benefits [Member] | Cash [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets		0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year		0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		$ 0		0
Other Postretirement Benefits [Member] | U.S. equity securities [Member] | Minimum [Member]
Actual return on plan assets:
Target plan allocation		30.00%
Other Postretirement Benefits [Member] | U.S. equity securities [Member] | Maximum [Member]
Actual return on plan assets:
Target plan allocation		43.00%
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	$ 10,493		10,493
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	10,493
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[8]	13,522		10,493
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - U.S. [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[8]	0		0
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - U.S. [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	10,493		10,493
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	10,493
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[8]	13,522		10,493
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - U.S. [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[8]	0		0
Other Postretirement Benefits [Member] | Mutual Fund - U.S. [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	4,723		4,723
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	4,723
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	1,309		4,723
Other Postretirement Benefits [Member] | Mutual Fund - U.S. [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	4,723		4,723
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	4,723
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	1,309		4,723
Other Postretirement Benefits [Member] | Mutual Fund - U.S. [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	0		0
Other Postretirement Benefits [Member] | Mutual Fund - U.S. [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	$ 0		0
Other Postretirement Benefits [Member] | International equity securities [Member] | Minimum [Member]
Actual return on plan assets:
Target plan allocation		20.00%
Other Postretirement Benefits [Member] | International equity securities [Member] | Maximum [Member]
Actual return on plan assets:
Target plan allocation		30.00%
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	$ 7,373		7,373
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	7,373
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[8]	8,313		7,373
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - International [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[8]	0		0
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - International [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	7,373		7,373
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	7,373
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[8]	8,313		7,373
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - International [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[8]	0		0
Other Postretirement Benefits [Member] | Mutual Fund - International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	1,795		1,795
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	1,795
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	983		1,795
Other Postretirement Benefits [Member] | Mutual Fund - International [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	1,795		1,795
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	1,795
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	0		1,795
Other Postretirement Benefits [Member] | Mutual Fund - International [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	983		0
Other Postretirement Benefits [Member] | Mutual Fund - International [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		$ 0		0	[9]
Other Postretirement Benefits [Member] | Fixed Income Funds [Member] | Minimum [Member]
Actual return on plan assets:
Target plan allocation		32.00%
Other Postretirement Benefits [Member] | Fixed Income Funds [Member] | Maximum [Member]
Actual return on plan assets:
Target plan allocation		42.00%
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	$ 11,597		11,597
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	11,597
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		13,187		11,597	[8]
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - Bonds [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0		0	[8]
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - Bonds [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	11,597		11,597
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	11,597
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		13,187		11,597	[8]
Other Postretirement Benefits [Member] | Common/Collective Trust Funds - Bonds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[8]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[8]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0		0	[8]
Other Postretirement Benefits [Member] | Mutual Funds - Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	2,820		2,820
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	2,820
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	1,441		2,820
Other Postretirement Benefits [Member] | Mutual Funds - Bonds [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	2,820		2,820
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	2,820
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	1,441		2,820
Other Postretirement Benefits [Member] | Mutual Funds - Bonds [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	0		0
Other Postretirement Benefits [Member] | Mutual Funds - Bonds [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	$ 0		0
Other Postretirement Benefits [Member] | Other Investments [Member] | Minimum [Member]
Actual return on plan assets:
Target plan allocation		0.00%
Other Postretirement Benefits [Member] | Other Investments [Member] | Maximum [Member]
Actual return on plan assets:
Target plan allocation		7.00%
Other Postretirement Benefits [Member] | Mutual Funds - REITs [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	$ 308		308
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	308
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	152		308
Other Postretirement Benefits [Member] | Mutual Funds - REITs [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	308		308
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	308
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[9]	152		308
Other Postretirement Benefits [Member] | Mutual Funds - REITs [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0		0	[9]
Other Postretirement Benefits [Member] | Mutual Funds - REITs [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[9]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[9]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0		0	[9]
Other Postretirement Benefits [Member] | Company Owned Life Insurance [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[10]	3,960		3,960
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[10]	3,960
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[10]	8,826		3,960
Other Postretirement Benefits [Member] | Company Owned Life Insurance [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[10]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[10]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		0		0	[10]
Other Postretirement Benefits [Member] | Company Owned Life Insurance [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[10]	3,960		3,960
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[10]	3,960
Actual return on plan assets:
Fair Value of Plan Assets at End of Year	[10]	8,826		3,960
Other Postretirement Benefits [Member] | Company Owned Life Insurance [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	[10]	0		0
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value of Plan Assets at Beginning of Year	[10]	0
Actual return on plan assets:
Fair Value of Plan Assets at End of Year		$ 0		$ 0	[10]
[1]	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.
[2]	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.
[3]	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.
[4]	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.
[5]	This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments.
[6]	This category represents a limited partnership/commingled trust which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 to 120 day lag and, therefore, the value reported herein represents the market value as of June 30 or September 30, 2015 and 2014, respectively, with cash flow changes through December applied. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments. Fund investments are illiquid and resale is restricted. These funds are classified as Level 3 investments.
[7]	This category represents real estate common/collective trust fund investments through a commingled employee benefit trust. These commingled funds are part of a direct investment in a pool of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals from sources with professional qualifications. Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments.
[8]	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.
[9]	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.
[10]	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.

PENSION AND OTHER POSTRETIREM73

PENSION AND OTHER POSTRETIREMENT BENEFITS - CONTRIBUTIONS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
Pension contribution	$ 15,000,000	$ 0	$ 12,700,000
Pension Benefits [Member]
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
2,016	11,409,000
2,017	11,846,000
2,018	12,376,000
2,019	13,374,000
2,020	13,954,000
2021- 2024	82,139,000
Pension contribution	15,000,000	0	12,700,000
Employer contributions	17,017,000	1,535,000
Other Postretirement Benefits [Member]
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
2,016	4,458,000
2,017	4,427,000
2,018	4,363,000
2,019	4,406,000
2,020	4,519,000
2021- 2024	21,933,000
Employer contributions	8,721,000	4,773,000
Expected contribution to plan	3,600,000
Supplemental Employee Retirement Plans, Defined Benefit [Member]
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
Employer contributions	2,000,000	$ 1,500,000	$ 1,300,000
Expected contribution to plan	$ 2,300,000

PENSION AND OTHER POSTRETIREM74

PENSION AND OTHER POSTRETIREMENT BENEFITS - DEFINED CONTRIBUTION PLAN (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)$ / employees	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Defined Benefit Plan Disclosure [Line Items]
Amount expensed and contributed for matching provision of Savings Plan | $	$ 2.1	$ 2	$ 1.7
Employees eligible for defined benefit pension plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Maximum annual contribution percentage	50.00%
Employer matching contribution, percentage	6.00%
Employees ineligible for defined benefit pension plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Maximum annual contribution percentage	50.00%
Employer matching contribution, percentage	8.00%
Year-end contribution (in USD per employee)	1,500
Service threshold to determine year-end contribution (more than) (in years)	10 years
Year-end contribution for employees with more then ten years of service	2,000

LINES OF CREDIT (Details)

LINES OF CREDIT (Details)		12 Months Ended
		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013
Line of Credit Facility [Line Items]
Total Facility		$ 610,000,000
Usage		442,000,000
Available Liquidity		168,000,000
Letters of credit outstanding		$ 8,100,000
Weighted average borrowing cost		1.13%	0.83%	1.04%
Average borrowings outstanding during the period		$ 335,000,000	$ 267,000,000
Maximum amounts outstanding during the period		$ 471,100,000	$ 390,700,000
Financial covenant, ratio of indebtedness to consolidated total capitalization (not more than)		0.65
Standby letters of credit [Member]
Line of Credit Facility [Line Items]
Total Facility		$ 8,100,000
South Jersey Gas Commercial Paper Program [Member]
Line of Credit Facility [Line Items]
Total Facility		$ 200,000,000
Fixed maturities of notes, at maximum number of days		270 days
South Jersey Gas Company [Member]
Line of Credit Facility [Line Items]
Total Facility		$ 210,000,000
Usage		136,600,000
Available Liquidity		73,400,000
South Jersey Gas Company [Member] | Standby letters of credit [Member]
Line of Credit Facility [Line Items]
Letters of credit outstanding		2,200,000
South Jersey Gas Company [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Total Facility		200,000,000
Usage	[1]	136,600,000
Available Liquidity		63,400,000
South Jersey Gas Company [Member] | Uncommitted Bank Lines [Member]
Line of Credit Facility [Line Items]
Total Facility		10,000,000
Usage		0
Available Liquidity		10,000,000
South Jersey Industries Inc [Member]
Line of Credit Facility [Line Items]
Total Facility		400,000,000
Usage		305,400,000
Available Liquidity		94,600,000
South Jersey Industries Inc [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Total Facility		400,000,000
Usage	[2]	305,400,000
Available Liquidity		$ 94,600,000
[1]	Includes letters of credit outstanding in the amount of $2.2 million.
[2]	Includes letters of credit outstanding in the amount of $8.1 million.

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details) - USD ($)		1 Months Ended				12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Aug. 31, 2015	Jun. 30, 2015	Dec. 31, 2015	Oct. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Aug. 31, 2014	Jun. 30, 2014
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1]	$ 1,035,848,000				$ 1,035,848,000		$ 1,009,400,000
Less Current Maturities	[1]	(29,454,000)				(29,454,000)		(149,909,000)
Total Long-Term Debt	[1]	1,006,394,000				1,006,394,000		859,491,000
Long-term Debt, Fiscal Year Maturity [Abstract]
2,016		29,454,000				29,454,000
2,017		172,558,000				172,558,000
2,018		40,667,000				40,667,000
2,019		260,783,000				260,783,000
2,020		74,476,000				74,476,000
Amount of facility		610,000,000				610,000,000
Guarantor obligations		$ 79,300,000				$ 79,300,000
Senior Notes [Member] | Series Due Jun 2019, 3.05% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage											3.05%
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt											$ 60,000,000
Senior Notes [Member] | Series Due Aug 2019, 3.05% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage										3.05%
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt										$ 30,000,000
Senior Notes [Member] | Series Due Sept 2019, 3.05% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage									3.05%
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt									$ 50,000,000
Senior Notes [Member] | Series Due June 2019, Floating Rate [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end		1.93%				1.93%
Amount of debt											40,000,000
Senior Notes [Member] | Series Due Sept 2019, Floating Rate [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt									$ 60,000,000
Senior Notes [Member] | June 2014 Note Purchase Agreement [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt											240,000,000
Medium-term Notes [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity		$ 400,000,000				$ 400,000,000
South Jersey Gas Company [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility		$ 210,000,000				$ 210,000,000
South Jersey Gas Company [Member] | Series Due 2015, 5.387% [Member] | Medium-term Notes [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		5.387%				5.387%
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt retired				$ 10,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2015, 5.387% [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[2],[3]	$ 0				$ 0		10,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2016, 5.437% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		5.437%				5.437%
Total Long-Term Debt Outstanding	[1],[3]	$ 10,000,000				$ 10,000,000		10,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2016, 4.6% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.60%				4.60%
Total Long-Term Debt Outstanding	[1],[3]	$ 17,000,000				$ 17,000,000		17,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2017, 4.657% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.657%				4.657%
Total Long-Term Debt Outstanding	[1],[3]	$ 15,000,000				$ 15,000,000		15,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2018, 7.97% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		7.97%				7.97%
Total Long-Term Debt Outstanding	[1],[3]	$ 10,000,000				$ 10,000,000		10,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2018, 7.125% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		7.125%				7.125%
Total Long-Term Debt Outstanding	[1],[3]	$ 20,000,000				$ 20,000,000		20,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2019, 5.587% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		5.587%				5.587%
Total Long-Term Debt Outstanding	[1],[3]	$ 10,000,000				$ 10,000,000		10,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2024, 3.00% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		3.00%				3.00%
Total Long-Term Debt Outstanding	[1],[3]	$ 50,000,000				$ 50,000,000		50,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2024, 3.03% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		3.03%				3.03%
Total Long-Term Debt Outstanding	[1],[3]	$ 35,000,000				$ 35,000,000		35,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2025, 3.63% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		3.63%				3.63%
Repayments of Debt		$ 900,000
Total Long-Term Debt Outstanding	[1],[3],[4]	$ 9,091,000				$ 9,091,000		10,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2026, 4.84% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.84%				4.84%
Total Long-Term Debt Outstanding	[1],[3]	$ 15,000,000				$ 15,000,000		15,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2026, 4.93% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.93%				4.93%
Total Long-Term Debt Outstanding	[1],[3]	$ 45,000,000				$ 45,000,000		45,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2027, 4.03% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.03%				4.03%
Total Long-Term Debt Outstanding	[1],[3]	$ 45,000,000				$ 45,000,000		45,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2030, 4.01% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.01%				4.01%
Total Long-Term Debt Outstanding	[1],[3]	$ 50,000,000				$ 50,000,000		50,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due January 2030, 4.23% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.23%				4.23%
Total Long-Term Debt Outstanding	[1],[3]	$ 30,000,000				$ 30,000,000		30,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2032, 3.74% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		3.74%				3.74%
Total Long-Term Debt Outstanding	[1],[3]	$ 35,000,000				$ 35,000,000		35,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2033, 5.55% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		5.55%				5.55%
Total Long-Term Debt Outstanding	[1],[3]	$ 32,000,000				$ 32,000,000		32,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2034, 6.213% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		6.213%				6.213%
Total Long-Term Debt Outstanding	[1],[3]	$ 10,000,000				$ 10,000,000		10,000,000
South Jersey Gas Company [Member] | First Mortgage Bonds [Member] | Series Due 2035, 5.45% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		5.45%				5.45%
Total Long-Term Debt Outstanding	[1],[3]	$ 10,000,000				$ 10,000,000		10,000,000
South Jersey Gas Company [Member] | Unsecured debt [Member] | Series A. 2006 Bonds [Member]
Debt Instrument [Line Items]
Repayments of Debt			$ 100,000
Total Long-Term Debt Outstanding	[1],[5]	$ 24,900,000				$ 24,900,000		25,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end		0.03%				0.03%
South Jersey Gas Company [Member] | Loans Payable [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[6]	$ 139,000,000				$ 139,000,000		59,000,000
Average interest rate		1.17%				1.17%
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility											$ 200,000,000
Marina Energy LLC [Member] | Energenic US LLC [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Equity interest		50.00%				50.00%
Marina Energy LLC [Member] | Unsecured debt [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding		$ 61,400,000				$ 61,400,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Outstanding amount of note not fixed by interest rate derivatives		$ 39,000,000				$ 39,000,000
Fixed interest rate		4.22%				4.22%
Marina Energy LLC [Member] | Unsecured debt [Member] | Series A. 2031 Bonds [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[7]	$ 20,000,000				$ 20,000,000		20,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end		0.04%				0.04%
Marina Energy LLC [Member] | Unsecured debt [Member] | Series B. 2021 Bonds [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[7]	$ 25,000,000				$ 25,000,000		25,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end		0.47%				0.47%
Marina Energy LLC [Member] | Unsecured debt [Member] | Series A. 2036 [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[7]	$ 16,400,000				$ 16,400,000		16,400,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end		0.04%				0.04%
South Jersey Industries Inc [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of facility		$ 400,000,000				$ 400,000,000
South Jersey Industries Inc [Member] | Unsecured debt [Member] | Term Loan Due 2015 [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[8]	$ 0				$ 0		50,000,000
South Jersey Industries Inc [Member] | Unsecured debt [Member] | Term Loan Due 2015 [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding							$ 50,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Interest rate at period end		1.28%				1.28%
South Jersey Industries Inc [Member] | Unsecured debt [Member] | Term Loan Due 2020 [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[8]	$ 50,000,000				$ 50,000,000		0
South Jersey Industries Inc [Member] | Senior Notes [Member] | Series A Notes Due 2015, 2.39% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		2.39%				2.39%
Total Long-Term Debt Outstanding	[1],[9]	$ 0				$ 0		64,000,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Amount of debt retired					$ 64,000,000
South Jersey Industries Inc [Member] | Senior Notes [Member] | Series B Notes Due 2017, 2.71% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		2.71%				2.71%
Total Long-Term Debt Outstanding	[1]	$ 16,000,000				$ 16,000,000		16,000,000
South Jersey Industries Inc [Member] | Senior Notes [Member] | Series Due Jun 2019, 3.05% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		3.05%				3.05%
Total Long-Term Debt Outstanding	[1],[10]	$ 60,000,000				$ 60,000,000		60,000,000
South Jersey Industries Inc [Member] | Senior Notes [Member] | Series Due Aug 2019, 3.05% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		3.05%				3.05%
Total Long-Term Debt Outstanding	[1],[10]	$ 30,000,000				$ 30,000,000		30,000,000
South Jersey Industries Inc [Member] | Senior Notes [Member] | Series Due Sept 2019, 3.05% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		3.05%				3.05%
Total Long-Term Debt Outstanding	[1],[10]	$ 50,000,000				$ 50,000,000		50,000,000
South Jersey Industries Inc [Member] | Senior Notes [Member] | Series C Notes Due 2022, 3.46% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		3.46%				3.46%
Total Long-Term Debt Outstanding	[1]	$ 35,000,000				$ 35,000,000		35,000,000
South Jersey Industries Inc [Member] | Senior Notes [Member] | Series Due June 2019, Floating Rate [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[10]	40,000,000				40,000,000		40,000,000
South Jersey Industries Inc [Member] | Senior Notes [Member] | Series Due Sept 2019, Floating Rate [Member]
Debt Instrument [Line Items]
Total Long-Term Debt Outstanding	[1],[10]	$ 60,000,000				$ 60,000,000		60,000,000
ACB Energy Partners, LLC [Member] | Loan and Security Agreement [Member] | Loan and Security Agreement Due 2021, 7.60% [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		7.60%				7.60%
Total Long-Term Debt Outstanding	[1],[11]	$ 12,735,000				$ 12,735,000		0
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity		$ 16,000,000				$ 16,000,000
AC Landfill Energy, LLC [Member] | Debt Agreement [Member] | Debt Agreement Due 2020, 4.83% Agreement 1 [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.83%				4.83%
Total Long-Term Debt Outstanding	[1],[12]	$ 3,551,000				$ 3,551,000		0
SC Landfill Energy, LLC [Member] | Debt Agreement [Member] | Debt Agreement Due 2020, 4.83% Agreement 2 [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.83%				4.83%
Total Long-Term Debt Outstanding	[1],[12]	$ 1,738,000				$ 1,738,000		0
SX Landfill Energy, LLC [Member] | Debt Agreement [Member] | Debt Agreement Due 2020, 4.83% Agreement 3 [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.83%				4.83%
Total Long-Term Debt Outstanding	[1],[12]	$ 3,433,000				$ 3,433,000		0
ACLE, SCLE and SXLE [Member] | Debt Agreement [Member]
Debt Instrument [Line Items]
Stated interest rate percentage		4.83%				4.83%
Total Long-Term Debt Outstanding		$ 8,700,000				$ 8,700,000		4,700,000
Long-term Debt, Fiscal Year Maturity [Abstract]
Maximum borrowing capacity		$ 10,000,000				$ 10,000,000
SJI's percentage of guarantee of the outstanding debt						50.00%
Guarantor obligations								$ 300,000
[1]	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2016, $29,454; 2017, $172,558; 2018,$40,667; 2019,$260,783; and 2020, $74,476.
[2]	In August 2015, SJG retired $10.0 million aggregate principal amount of 5.387% Medium Term Notes (MTN's) at maturity.
[3]	The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant.
[4]	In December 2015, SJG paid $0.9 million toward the principal amount of 3.63% MTN's due December 2025.
[5]	In September 2015, SJG paid $0.1 million toward the principal amount of variable rate demand bonds due February 2036. These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2015 was 0.03%. 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.
[6]	In June 2014, SJG entered into a $200.0 million multiple-draw term facility offered by a syndicate of banks which expires in June 2017. SJG can draw under this facility through June 2016 and this facility bears 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.
[7]	Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2015 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.04%, 0.47% and 0.04% respectively. The interest rate on all but $39.0 million of the bonds has been effectively fixed via interest rate swaps at 4.22% until January 2026. These bonds contain no financial covenants. Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in March, 2016. The Company has plans to renew this letter of credit facility upon expiration.
[8]	In October 2015, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2020. This agreement replaced existing facilities that expired in October 2015. The variable rate at December 31, 2015 was 1.28%.
[9]	In June 2015, SJI redeemed at maturity $64.0 million aggregate principal amount of 2.39% Senior Notes.
[10]	In June 2014, SJI entered into a Note Purchase Agreement that provided for SJI to issue an aggregate of $240.0 million of medium term notes, all of which were issued as follows: (a) in June 2014, SJI issued $60.0 million aggregate principal amount of 3.05% Senior Notes due June 2019, and $40.0 million aggregate principal amount of Floating Rate Senior Notes due June 2019; (b) in August 2014, SJI issued $30.0 million aggregate principal amount of 3.05% Senior Notes due August 2019; and (c) in September 2014, SJI issued $50.0 million aggregate principal amount of 3.05% Senior Notes due September 2019, and $60.0 million aggregate principal amount of Floating Rate Senior Notes due September 2019. At December 31, 2015, the floating rate was 1.93%.
[11]	ACB has a Loan and Security Agreement (“LSA”) with a third party to borrow up to $16.0 million. Under the LSA, ACB pays principal and interest (at a fixed rate of 7.60%) in equal quarterly installments that began in February 2011 and run through February 2021. As of December 31, 2014, ACB was a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest. In December 2015, ACB became a wholly-owned subsidiary of Marina (see Note 3); as such, the remaining outstanding debt of $12.7 million is included on the consolidated balance sheets as of December 31, 2015. The remaining debt was paid in January 2016 (see Note 19).
[12]	ACLE, SCLE and SXLE (the "Other Energy Projects") have long-term debt agreements with a third party to borrow up to $10.0 million. Under the debt agreement, the Other Energy Projects pay principal and interest (at a fixed rate of 4.83%) in equal installments that began December 2013 and run through December 2020. As of December 31, 2014, the Other Energy Projects were wholly-owned subsidiaries of Energenic, of which Marina had a 50% equity interest. SJI had agreements to guarantee 50% of the outstanding debt, which was $4.7 million as of December 31, 2014, and the Company had recorded $0.3 million for the fair value of the guarantees on the consolidated balance sheets as of December 31, 2014. In December 2015, the Other Energy Projects became wholly-owned subsidiaries of Marina (see Note 3); as such, the remaining outstanding debt of $8.7 million is included on the consolidated balance sheets as of December 31, 2015.

COMMITMENTS AND CONTINGENCIES77

COMMITMENTS AND CONTINGENCIES (Details)	12 Months Ended		432 Months Ended
	Dec. 31, 2015USD ($)sitedecatherm / dayunion	Dec. 31, 2014USD ($)	Dec. 31, 2015USD ($)sitedecatherm / dayunion
Commitment and Contingencies [Line Items]
Minimum purchase amount under contract (in dts/d) | decatherm / day	626,500		626,500
Maximum purchase amount under contract (in dts/d) | decatherm / day	796,250		796,250
Minimum length of contract term	3 years
Maximum length of contract term	10 years
Accrual for pending litigation	$ 3,200,000	$ 2,900,000	$ 3,200,000
Collective bargaining agreements [Abstract]
Percentage of personnel represented by collective bargaining agreements	45.00%		45.00%
Number of unions for which entity has collect bargaining agreements with | union	2		2
Guarantees [Abstract]
Guarantor obligations	$ 79,300,000		$ 79,300,000
Standby letters of credit [Abstract]
Letter of credit provided	$ 610,000,000		$ 610,000,000
Environmental remediation costs [Abstract]
Number of sites for environmental cleanup (in number of sites) | site	12		12
Number of sites covered by insurance | site	11		11
Insurance policy limit	$ 50,000,000		$ 50,000,000
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning of Year	128,172,000	123,429,000
Accruals	19,489,000	18,533,000	377,200,000
Expenditures	(21,038,000)	(13,790,000)	(250,600,000)
End of Year	126,623,000	$ 128,172,000	126,623,000
Standby letters of credit [Member]
Standby letters of credit [Abstract]
Letter of credit provided	8,100,000		8,100,000
Standby Letter of Credit, Variable-rate Demand Bonds [Member]
Standby letters of credit [Abstract]
Letter of credit provided	87,500,000		87,500,000
Environmental Restoration Costs [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Minimum amount of future clean up costs	123,200,000		123,200,000
Maximum amount of future clean up costs	204,700,000		204,700,000
Minimum amount of future clean up costs assumed by another entity	2,800,000		2,800,000
Maximum amount of future clean up costs assumed by another entity	4,200,000		4,200,000
Environmental Restoration Costs [Member] | Fuel Oil [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Minimum amount of future clean up costs	600,000		600,000
Maximum amount of future clean up costs	$ 1,300,000		$ 1,300,000
Number of sites affected by environmental remediation | site	6		6
Environmental Restoration Costs [Member] | Sites Comprising the Majority the Environmental Remediation [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Minimum amount of future clean up costs	$ 110,500,000		$ 110,500,000
Maximum amount of future clean up costs	$ 190,500,000		$ 190,500,000
Number of sites affected by environmental remediation | site	6		6
Parental Guarantee [Member]
Guarantees [Abstract]
Contract term	2 years
Capital contribution obligation [Abstract]
Guaranteed amount	$ 5,200,000		$ 5,200,000
South Jersey Resources Group, LLC [Member]
Commitment and Contingencies [Line Items]
Amount of monthly fees paid to supplier	500,000
South Jersey Gas Company [Member]
Commitment and Contingencies [Line Items]
Amount of monthly fees paid to supplier	6,300,000
Standby letters of credit [Abstract]
Letter of credit provided	$ 210,000,000		$ 210,000,000

DERIVATIVE INSTRUMENTS (Details

DERIVATIVE INSTRUMENTS (Details) MWh in Millions	12 Months Ended
	Dec. 31, 2015USD ($)MWh		Dec. 31, 2015USD ($)MMcfe
Marina Energy LLC [Member] | Interest Rate Swap, 14,500,000 [Member]
Derivative [Line Items]
Notional Amount	$ 14,500,000		$ 14,500,000
Fixed Interest Rate	3.905%		3.905%
Marina Energy LLC [Member] | Interest Rate Swap, 500,000 [Member]
Derivative [Line Items]
Notional Amount	$ 500,000		$ 500,000
Fixed Interest Rate	3.905%		3.905%
Marina Energy LLC [Member] | Interest Rate Swap, 330,000 [Member]
Derivative [Line Items]
Notional Amount	$ 330,000		$ 330,000
Fixed Interest Rate	3.905%		3.905%
Marina Energy LLC [Member] | Interest Rate Swap, 7,100,000 [Member]
Derivative [Line Items]
Notional Amount	$ 7,100,000	[1]	$ 7,100,000	[1]
Fixed Interest Rate	4.895%	[1]	4.895%	[1]
South Jersey Gas Company [Member] | Interest Rate Swap, 12,500,000 Contract 1 [Member]
Derivative [Line Items]
Notional Amount	$ 12,500,000		$ 12,500,000
Fixed Interest Rate	3.43%		3.43%
South Jersey Gas Company [Member] | Interest Rate Swap, 12,500,000 Contract 2 [Member]
Derivative [Line Items]
Notional Amount	$ 12,500,000		$ 12,500,000
Fixed Interest Rate	3.43%		3.43%
Basis and index related purchase and sales contracts [Member]
Derivative [Line Items]
Notional amount, energy | MMcfe			179,000
Purchase transaction [Member]
Derivative [Line Items]
Notional amount, energy	3.2		82,100
Sale transaction [Member]
Derivative [Line Items]
Notional amount, energy	3		70,100
[1]	The Company currently does not have any plans to renew this interest rate swap.

DERIVATIVE INSTRUMENTS - FAIR V

DERIVATIVE INSTRUMENTS - FAIR VALUES OF ALL DERIVATIVE INSTRUMENTS (Details) - Not designated as hedging instruments under GAAP [Member] - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Assets	$ 99,331	$ 99,273
Liabilities	123,348	140,402
Commodity contract [Member] | Derivatives - Energy Related - Current [Member]
Derivatives, Fair Value [Line Items]
Assets	83,093	85,368
Liabilities	90,708	109,744
Commodity contract [Member] | Derivatives - Energy Related - Non-Current [Member]
Derivatives, Fair Value [Line Items]
Assets	16,238	13,905
Liabilities	21,697	19,926
Interest rate contract [Member] | Derivatives - Other [Member]
Derivatives, Fair Value [Line Items]
Assets	0	0
Liabilities	$ 10,943	$ 10,732

DERIVATIVE INSTRUMENTS - OFFSET

DERIVATIVE INSTRUMENTS - OFFSETTING ARRANGEMENTS (Details) - USD ($) $ in Thousands		Dec. 31, 2015	Dec. 31, 2014
Derivatives - Energy Related [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities		$ 99,331	$ 99,273
Gross amount offset in the balance sheet		0	0
Net amounts of assets/liabilities in balance sheet		99,331	99,273
Gross amounts not offset in the balance sheet, Financial Instruments	[1]	(35,491)	(39,747)
Gross amounts not offset in the balance sheet, Cash Collateral Posted		0	0
Net amount		63,840	59,526
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities		(112,405)	(129,670)
Gross amount offset in the balance sheet		0	0
Net amounts of assets/liabilities in balance sheet		(112,405)	(129,670)
Gross amounts not offset in the balance sheet, Financial Instruments	[2]	35,491	39,747
Gross amounts not offset in the balance sheet, Cash Collateral Posted		23,045	53,897
Net amount		(53,869)	(36,026)
Derivatives - Other [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities		(10,943)	(10,732)
Gross amount offset in the balance sheet		0	0
Net amounts of assets/liabilities in balance sheet		(10,943)	(10,732)
Gross amounts not offset in the balance sheet, Financial Instruments		0	0
Gross amounts not offset in the balance sheet, Cash Collateral Posted		0	0
Net amount		$ (10,943)	$ (10,732)
[1]	The balances at December 31, 2015 and 2014 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at December 31, 2015 and 2014 were related to derivative assets which can be net settled against derivative liabilities.

DERIVATIVE INSTRUMENTS - EFFECT

DERIVATIVE INSTRUMENTS - EFFECTS OF DERIVATIVE INSTRUMENTS (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Interest Rate Contracts [Abstract]
Losses recognized in AOCL on effective portion		$ 0	$ 0	$ 0
Losses reclassified from AOCL into income	[1]	(551)	(419)	(448)
Losses recognized in income on ineffective portion	[1]	0	0	0
Losses on energy related commodity contracts	[2]	8,401	(6,592)	(25,823)
(Losses) gains on interest rate contracts	[3]	96	(467)	2,760
Total		8,497	(7,059)	(23,063)
Realized gains (losses) on derivative instruments on energy-related contracts		(9,100)	$ 1,700	$ (400)
Fair value derivative instruments with credit-risk-related features		48,700
Additional collateral, aggregate fair value		$ 45,000
[1]	Included in Interest Charges
[2]	Included in Operating Revenues - Nonutility
[3]	Included in Interest Charges

FAIR VALUE OF FINANCIAL ASSET82

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) $ in Thousands		12 Months Ended
		Dec. 31, 2015USD ($)$ / decatherm	Dec. 31, 2014USD ($)$ / decatherm
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period		$ (5,608)	$ 8,095
Other changes in fair value from continuing and new contracts, net		(5,069)	(17,153)
Transfers in to/(out of )Level 3	[1]	7,402
Settlements		2,643	3,450
Balance at end of period		$ (632)	$ (5,608)
Level 3 [Member] | Forward contracts [Member] | Minimum [Member]
Liabilities
Forward price (in USD per dt) | $ / decatherm	[2]	(0.77)	(2.04)
Level 3 [Member] | Forward contracts [Member] | Maximum [Member]
Liabilities
Forward price (in USD per dt) | $ / decatherm	[2]	10	7.83
Level 3 [Member] | Forward contracts [Member] | Weighted average [Member]
Liabilities
Forward price (in USD per dt) | $ / decatherm	[2]	(2.15)	(0.30)
Level 3 [Member] | Forward contracts [Member] | Natural gas [Member]
Liabilities
Assets		$ 29,459	$ 26,485
Liabilities		31,733	33,882
Level 3 [Member] | Forward contracts [Member] | Electricity [Member]
Liabilities
Assets		29,136	8,020
Liabilities		$ 27,494	$ 6,231
Level 3 [Member] | Forward contracts [Member] | Electricity [Member] | Minimum [Member] | On-peak [Member]
Liabilities
Fixed electric load profile	[3]	8.47%	8.06%
Level 3 [Member] | Forward contracts [Member] | Electricity [Member] | Minimum [Member] | Off-peak [Member]
Liabilities
Fixed electric load profile	[3]	0.00%	0.00%
Level 3 [Member] | Forward contracts [Member] | Electricity [Member] | Maximum [Member] | On-peak [Member]
Liabilities
Fixed electric load profile	[3]	100.00%	100.00%
Level 3 [Member] | Forward contracts [Member] | Electricity [Member] | Maximum [Member] | Off-peak [Member]
Liabilities
Fixed electric load profile	[3]	91.53%	91.94%
Level 3 [Member] | Forward contracts [Member] | Electricity [Member] | Weighted average [Member] | On-peak [Member]
Liabilities
Fixed electric load profile	[3]	56.20%	55.97%
Level 3 [Member] | Forward contracts [Member] | Electricity [Member] | Weighted average [Member] | Off-peak [Member]
Liabilities
Fixed electric load profile	[3]	43.80%	44.03%
Measurement at fair value on recurring basis [Member]
Assets
Available-for-Sale Securities	[4]	$ 14,810	$ 8,922
Derivatives - Energy Related Assets	[5]	99,331	99,273
Assets		114,141	108,195
Liabilities
Derivatives - Energy Related Liabilities	[5]	112,405	129,670
Derivatives - Other	[6]	10,943	10,732
Liabilities		123,348	140,402
Measurement at fair value on recurring basis [Member] | Level 1 [Member]
Assets
Available-for-Sale Securities	[4]	2,925	5,952
Derivatives - Energy Related Assets	[5]	16,006	21,675
Assets		18,931	27,627
Liabilities
Derivatives - Energy Related Liabilities	[5]	42,170	49,009
Derivatives - Other	[6]	0	0
Liabilities		42,170	49,009
Measurement at fair value on recurring basis [Member] | Level 2 [Member]
Assets
Available-for-Sale Securities	[4]	11,885	2,970
Derivatives - Energy Related Assets	[5]	24,730	43,093
Assets		36,615	46,063
Liabilities
Derivatives - Energy Related Liabilities	[5]	11,008	40,548
Derivatives - Other	[6]	10,943	10,732
Liabilities		21,951	51,280
Measurement at fair value on recurring basis [Member] | Level 3 [Member]
Assets
Available-for-Sale Securities	[4]	0	0
Derivatives - Energy Related Assets	[5]	58,595	34,505
Assets		58,595	34,505
Liabilities
Derivatives - Energy Related Liabilities	[5]	59,227	40,113
Derivatives - Other	[6]	0	0
Liabilities		$ 59,227	$ 40,113
[1]	Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the year ended December 31, 2015, $7.4 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data, which is assessed quarterly by management.
[2]	Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas.
[3]	Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak.
[4]	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.
[5]	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 forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
[6]	Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

ACCUMULATED OTHER COMPREHENSI83

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at January 1	[1]	$ (30,258)
Other comprehensive income before reclassifications		1,351
Amounts reclassified from AOCL	[2]	4,408
Other Comprehensive (Loss) Income - Net of Tax	[3]	5,759		$ (9,498)		$ 10,345
Balance at December 31	[1]	$ (24,499)		$ (30,258)
Combined statutory tax rate		40.00%		40.00%		41.00%
Postretirement Liability Adjustment [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at January 1	[3]	$ (27,663)	[1]	$ (18,503)		$ (23,437)
Other comprehensive income before reclassifications		1,427
Amounts reclassified from AOCL	[2]	4,091
Other Comprehensive (Loss) Income - Net of Tax	[3]	5,518		(9,160)		4,934
Balance at December 31	[3]	(22,145)	[1]	(27,663)	[1]	(18,503)
Unrealized Gain (Loss) on Derivatives-Other [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at January 1	[3]	(2,450)	[1]	(2,697)		(2,962)
Other comprehensive income before reclassifications		0
Amounts reclassified from AOCL	[2]	321
Other Comprehensive (Loss) Income - Net of Tax	[3]	321		247		265
Balance at December 31	[3]	(2,129)	[1]	(2,450)	[1]	(2,697)
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at January 1	[3]	(75)	[1]	397		294
Other comprehensive income before reclassifications		(76)
Amounts reclassified from AOCL	[2]	23
Other Comprehensive (Loss) Income - Net of Tax	[3]	(53)		(472)		103
Balance at December 31	[3]	(128)	[1]	(75)	[1]	$ 397
Other Comprehensive Income (Loss) of Affiliated Companies [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance at January 1	[1]	(70)
Other comprehensive income before reclassifications		0
Amounts reclassified from AOCL	[2]	(27)
Other Comprehensive (Loss) Income - Net of Tax		(27)
Balance at December 31	[1]	$ (97)		$ (70)
[1]	Determined using a combined average statutory tax rate of 40%.
[2]	See table below.
[3]	For 2015 and 2014, determined using a combined average statutory tax rate of 40%. For 2013, determined using a combined statutory tax rate of 41%.

ACCUMULATED OTHER COMPREHENSI84

ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL) - RECLASSIFICATIONS OUT OF AOCL (Details) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Operations										$ 148,672	$ 140,260	$ 120,205
Interest Charges										31,622	29,560	18,825
Other Income										(9,510)	(11,819)	(10,979)
Equity in Loss of Affiliated Companies										27,812	7,785	(1,585)
Income Taxes		$ (1,006)	$ (10,968)	$ (3,279)	$ 16,613	$ 10,415	$ (8,325)	$ (9,510)	$ 11,869	1,360	4,449	(19,014)
Income from Continuing Operations		$ (50,948)	$ 12,532	$ (13,341)	$ (53,853)	$ (43,992)	$ 4,276	$ (9,701)	$ (48,211)	$ (105,610)	$ (97,628)	$ (82,389)
Combined statutory tax rate										40.00%	40.00%	41.00%
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Income from Continuing Operations										$ 4,408
Reclassification out of Accumulated Other Comprehensive Income [Member] | Actuarial Loss on Postretirement Benefits [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Operations										6,763
Income Taxes	[1]									(2,672)
Income from Continuing Operations										4,091
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges										551
Income Taxes	[1]									(230)
Income from Continuing Operations										321
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Loss on Available-for-Sale Securities [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Other Income										37
Income Taxes	[1]									(14)
Income from Continuing Operations										23
Reclassification out of Accumulated Other Comprehensive Income [Member] | Income of Affiliated Companies [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Equity in Loss of Affiliated Companies										(45)
Income Taxes	[1]									18
Income from Continuing Operations										$ (27)
[1]	Determined using a combined average statutory tax rate of 40%.

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Jan. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Subsequent Event [Line Items]
Repayments of debt to third party		$ 125,009	$ 21,000	$ 25,000
Subsequent event [Member]
Subsequent Event [Line Items]
Repayments of debt to third party	$ 12,700

Quarterly Financial Data (Una86

Quarterly Financial Data (Unaudited) (Details) $ / shares in Units, shares in Thousands, $ in Thousands	May. 08, 2015	Feb. 26, 2015	Dec. 31, 2015USD ($)$ / sharesshares	Sep. 30, 2015USD ($)$ / sharesshares	Jun. 30, 2015USD ($)$ / sharesshares	Mar. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares	Sep. 30, 2014USD ($)$ / sharesshares	Jun. 30, 2014USD ($)$ / sharesshares	Mar. 31, 2014USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares	Dec. 31, 2013USD ($)$ / sharesshares
Quarterly Financial Information Disclosure [Abstract]
Operating Revenues			$ 257,844	$ 141,062	$ 177,710	$ 382,952	$ 281,097	$ 122,427	$ 133,271	$ 350,201	$ 959,568	$ 886,996	$ 731,421
Expenses:
Cost of Sales - (Excluding depreciation)			127,566	99,124	90,945	241,707	153,794	76,073	78,947	228,138
Operations and Maintenance Including Fixed Charges			71,148	63,867	62,634	71,279	69,384	56,039	56,174	64,684
Income Taxes			(1,006)	(10,968)	(3,279)	16,613	10,415	(8,325)	(9,510)	11,869	1,360	4,449	(19,014)
Energy and Other Taxes			1,334	1,231	1,265	2,196	1,330	1,196	1,241	1,953	6,026	5,720	9,816
Total Expenses			199,042	153,254	151,565	331,795	234,923	124,983	126,852	306,644
Other Income and Expense			(7,854)	(340)	(12,804)	2,696	(2,182)	(1,720)	3,282	4,654
Income from Continuing Operations			50,948	(12,532)	13,341	53,853	43,992	(4,276)	9,701	48,211	105,610	97,628	82,389
Loss from Discontinued Operations - (Net of tax benefit)			(62)	(91)	(74)	(276)	(69)	(120)	(80)	(313)	$ (503)	$ (582)	$ (796)
Net Income (Loss)			$ 50,886	$ (12,623)	$ 13,267	$ 53,577	$ 43,923	$ (4,396)	$ 9,621	$ 47,898
Basic Earnings Per Common Share:
Continuing Operations (in USD per share) | $ / shares			$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 0.66	$ (0.07)	$ 0.15	$ 0.74	$ 1.54	$ 1.47	$ 1.29
Discontinued Operations (in USD per share) | $ / shares			0	0	0	0	0	0	0	0	0.01	0.01	0.01
Basic Earnings per Common Share (in USD per share) | $ / shares			$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 0.66	$ (0.07)	$ 0.15	$ 0.74	$ 1.53	$ 1.46	$ 1.28
Average Shares of Common Stock Outstanding - Basic (in shares) | shares			69,460	68,607	68,467	68,397	67,304	66,332	65,926	65,530	68,735	66,278	63,978
Diluted Earnings Per Common Share:
Continuing Operations (in USD per share) | $ / shares			$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 0.65	$ (0.07)	$ 0.15	$ 0.74	$ 1.53	$ 1.47	$ 1.29
Discontinued Operations (in USD per share) | $ / shares			0	0	0	0	0	0	0	0	0.01	0.01	0.01
Diluted Earnings per Common Share (in USD per share) | $ / shares			$ 0.73	$ (0.18)	$ 0.19	$ 0.79	$ 0.65	$ (0.07)	$ 0.15	$ 0.74	$ 1.52	$ 1.46	$ 1.28
Average Shares of Common Stock Outstanding - Diluted (in shares) | shares			69,646	68,607	68,653	68,618	67,454	66,332	66,074	65,684	68,931	66,428	64,092
Stock split, conversion ratio	2	2

Schedule I (Details)

Schedule I (Details) - USD ($)		3 Months Ended								12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2015	Feb. 26, 2015	Feb. 25, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Expenses:
Operations										$ 148,672,000	$ 140,260,000	$ 120,205,000
Depreciation										72,451,000	63,004,000	49,637,000
Energy and Other Taxes		$ 1,334,000	$ 1,231,000	$ 1,265,000	$ 2,196,000	$ 1,330,000	$ 1,196,000	$ 1,241,000	$ 1,953,000	6,026,000	5,720,000	9,816,000
Operating Income										156,894,000	127,603,000	69,636,000
Other Income:
Equity in Earnings of Subsidiaries										(27,812,000)	(7,785,000)	1,585,000
Total Other Income										9,510,000	11,819,000	10,979,000
Interest Charges										31,622,000	29,560,000	18,825,000
Income Taxes		(1,006,000)	(10,968,000)	(3,279,000)	16,613,000	10,415,000	(8,325,000)	(9,510,000)	11,869,000	1,360,000	4,449,000	(19,014,000)
Income from Continuing Operations		50,948,000	(12,532,000)	13,341,000	53,853,000	43,992,000	(4,276,000)	9,701,000	48,211,000	105,610,000	97,628,000	82,389,000
Equity in Undistributed Earnings of Discontinued Operations		(62,000)	$ (91,000)	$ (74,000)	(276,000)	(69,000)	$ (120,000)	$ (80,000)	(313,000)	(503,000)	(582,000)	(796,000)
Net Income										105,107,000	97,046,000	81,593,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net Income										105,107,000	97,046,000	81,593,000
Other Comprehensive (Loss) Income - Net of Tax
Postretirement Liability Adjustment	[1]									5,518,000	(9,160,000)	4,934,000
Unrealized (Loss) Gain on Available-for-Sale Securities	[1]									(53,000)	(472,000)	103,000
Unrealized Gain on Derivatives - Other	[1]									321,000	247,000	265,000
Other Comprehensive (Loss) Income - Net of Tax	[1]									$ 5,759,000	$ (9,498,000)	$ 10,345,000
Combined statutory tax rate										40.00%	40.00%	41.00%
Retained Earnings [Roll Forward]
Retained Earnings - Beginning					439,218,000					$ 439,218,000
Net Income										105,107,000	$ 97,046,000	$ 81,593,000
Dividends Declared - Common Stock										(70,158,000)	(63,869,000)	(57,679,000)
Retained Earnings - Ending		474,167,000				439,218,000				474,167,000	439,218,000
Statement of Cash Flows [Abstract]
CASH PROVIDED BY OPERATING ACTIVITIES										186,794,000	161,332,000	159,535,000
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital Expenditures										(345,621,000)	(342,578,000)	(316,644,000)
Proceeds from Sale of Property, Plant & Equipment										0	53,000	0
Purchase of Company-Owned Life Insurance										(2,328,000)	(1,250,000)	(5,149,000)
Net Cash Used in Investing Activities										(370,652,000)	(375,019,000)	(245,792,000)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Long Term Debt										130,000,000	329,000,000	50,000,000
Principal Repayments of Long Term Debt										(125,009,000)	(21,000,000)	(25,000,000)
Payments for Issuance of Long Term Debt										(64,000)	(2,184,000)	(411,000)
Net Borrowings from (Repayments of) Lines of Credits										186,000,000	(108,200,000)	65,000,000
Dividends on Common Stock										(70,158,000)	(63,869,000)	(57,679,000)
Net Cash Provided by Financing Activities										183,564,000	214,040,000	85,437,000
Net (Decrease) Increase in Cash and Cash Equivalents										(294,000)	353,000	(820,000)
Cash and Cash Equivalents at Beginning of Year					4,171,000				3,818,000	4,171,000	3,818,000	4,638,000
Cash and Cash Equivalents at End of Year		3,877,000				4,171,000				3,877,000	4,171,000	3,818,000
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost													$ 785,646,000			$ 622,079,000
Accumulated Depreciation													(108,307,000)			(77,345,000)
Property, Plant and Equipment - Net													2,448,105,000			2,134,103,000
Investments:
Available-for-Sale Securities													14,810,000			8,922,000
Total Investments													80,551,000			142,724,000
Current Assets:
Cash and Cash Equivalents		3,877,000			4,171,000	4,171,000			3,818,000	4,171,000	3,818,000	4,638,000	3,877,000			4,171,000	$ 3,818,000	$ 4,638,000
Other													40,167,000			18,686,000
Total Current Assets													431,274,000			566,697,000
Other Noncurrent Assets													64,575,000			61,124,000
Total Assets													3,480,900,000			3,349,425,000
Equity:
Common Stock SJI, Par Value $1.25, Authorized 120,000,000 shares, Outstanding - 70,965,622 (2015) shares and 68,334,860 (2014)													88,707,000			85,418,000	$ 81,788,000
Premium on Common Stock													499,460,000			438,384,000
Treasury Stock (at par)													(296,000)			(330,000)
Accumulated Other Comprehensive Loss	[2]												(24,499,000)			(30,258,000)
Retained Earnings		474,167,000			439,218,000	439,218,000				439,218,000	439,218,000		474,167,000			439,218,000
Total Equity													1,037,539,000			932,432,000
Long-Term Debt	[3]												1,035,848,000			1,009,400,000
Current Liabilities:
Notes Payable - Banks													431,700,000			245,700,000
Current Portion of Long-Term Debt	[3]												29,454,000			149,909,000
Accounts Payable													186,400,000			272,998,000
Other Current Liabilities													11,596,000			12,480,000
Total Current Liabilities													832,476,000			850,185,000
Other Noncurrent Liabilities													22,990,000			14,815,000
Total Capitalization and Liabilities													$ 3,480,900,000			$ 3,349,425,000
Common stock, par value (in USD per share)													$ 1.25			$ 1.25
Common Stock, authorized (in shares)													120,000,000	120,000,000	60,000,000	120,000,000
Common Stock, outstanding (in shares)													70,965,622			68,334,860	65,430,084	63,306,524
SOUTH JERSEY INDUSTRIES, INC. [Member]
Income Statement [Abstract]
Management Service Fee Revenues										20,990,000	21,118,000	16,269,000
Operating Expenses:
Operations										17,979,000	18,183,000	14,979,000
Depreciation										406,000	439,000	260,000
Energy and Other Taxes										806,000	813,000	465,000
Total Operating Expenses										19,191,000	19,435,000	15,704,000
Operating Income										1,799,000	1,683,000	565,000
Other Income:
Equity in Earnings of Subsidiaries										105,610,000	97,628,000	82,389,000
Other										10,145,000	7,283,000	5,459,000
Total Other Income										115,755,000	104,911,000	87,848,000
Interest Charges										11,822,000	8,803,000	6,004,000
Income Taxes										122,000	163,000	20,000
Income from Continuing Operations										105,610,000	97,628,000	82,389,000
Equity in Undistributed Earnings of Discontinued Operations										(503,000)	(582,000)	(796,000)
Net Income										105,107,000	97,046,000	81,593,000
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net Income										105,107,000	97,046,000	81,593,000
Other Comprehensive (Loss) Income - Net of Tax
Postretirement Liability Adjustment	[4]									5,518,000	(9,160,000)	4,934,000
Unrealized (Loss) Gain on Available-for-Sale Securities	[4]									(53,000)	(472,000)	103,000
Unrealized Gain on Derivatives - Other	[4]									294,000	134,000	5,308,000
Other Comprehensive (Loss) Income - Net of Tax	[4]									5,759,000	(9,498,000)	10,345,000
Comprehensive Income										110,866,000	87,548,000	91,938,000
Retained Earnings [Roll Forward]
Retained Earnings - Beginning					439,218,000				406,041,000	439,218,000	406,041,000	382,127,000
Net Income										105,107,000	97,046,000	81,593,000
Retained Earnings (Accumulated Deficit) After Net Income Before Dividends Declared													$ 544,325,000			$ 503,087,000	$ 463,720,000
Dividends Declared - Common Stock										(70,158,000)	(63,869,000)	(57,679,000)
Retained Earnings - Ending		474,167,000				439,218,000				474,167,000	439,218,000	406,041,000
Statement of Cash Flows [Abstract]
CASH PROVIDED BY OPERATING ACTIVITIES										38,593,000	22,244,000	1,316,000
CASH FLOWS FROM INVESTING ACTIVITIES:
Net Advances to Associated Companies										(118,802,000)	(104,979,000)	(68,900,000)
Capital Expenditures										(150,000)	(1,610,000)	(360,000)
Proceeds from Sale of Property, Plant & Equipment										0	27,000	6,000
Purchase of Company-Owned Life Insurance										(2,328,000)	(1,250,000)	(5,149,000)
Investment in Affiliate										0	(25,000,000)	(25,000,000)
Net Cash Used in Investing Activities										(121,280,000)	(132,812,000)	(99,403,000)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from Issuance of Long Term Debt										50,000,000	240,000,000	0
Principal Repayments of Long Term Debt										(114,000,000)	0	0
Payments for Issuance of Long Term Debt										(55,000)	(1,558,000)	0
Net Borrowings from (Repayments of) Lines of Credits										153,000,000	(144,100,000)	101,600,000
Dividends on Common Stock										(70,158,000)	(63,869,000)	(57,679,000)
Proceeds from Sale of Common Stock										63,192,000	80,680,000	54,028,000
Net Cash Provided by Financing Activities										81,979,000	111,153,000	97,949,000
Net (Decrease) Increase in Cash and Cash Equivalents										(708,000)	585,000	(138,000)
Cash and Cash Equivalents at Beginning of Year					2,416,000				1,831,000	2,416,000	1,831,000	1,969,000
Cash and Cash Equivalents at End of Year		1,708,000				2,416,000				1,708,000	2,416,000	1,831,000
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost													2,468,000			3,521,000
Accumulated Depreciation													(1,768,000)			(1,370,000)
Property, Plant and Equipment - Net													700,000			2,151,000
Investments:
Investments in Subsidiaries													1,051,675,000			983,721,000
Available-for-Sale Securities													3,860,000			28,000
Total Investments													1,055,535,000			983,749,000
Current Assets:
Cash and Cash Equivalents		1,708,000			2,416,000	2,416,000			1,831,000	2,416,000	1,831,000	1,969,000	1,708,000			2,416,000	1,831,000	$ 1,969,000
Receivable from Associated Companies													582,406,000			463,756,000
Accounts Receivable													49,000			35,000
Other													2,859,000			747,000
Total Current Assets													587,022,000			466,954,000
Other Noncurrent Assets													39,503,000			44,887,000
Total Assets													1,682,760,000			1,497,741,000
Equity:
Common Stock SJI, Par Value $1.25, Authorized 120,000,000 shares, Outstanding - 70,965,622 (2015) shares and 68,334,860 (2014)													88,707,000			42,709,000
Premium on Common Stock													499,460,000			480,928,000
Treasury Stock (at par)													(296,000)			(165,000)
Accumulated Other Comprehensive Loss													(24,499,000)			(30,258,000)
Retained Earnings		$ 474,167,000			$ 439,218,000	$ 439,218,000			$ 406,041,000	439,218,000	406,041,000	382,127,000	474,167,000			439,218,000	$ 406,041,000	$ 382,127,000
Total Equity													1,037,539,000			932,432,000
Long-Term Debt													341,000,000			291,000,000
Current Liabilities:
Notes Payable - Banks													297,300,000			144,300,000
Current Portion of Long-Term Debt													0			114,000,000
Payable to Associated Companies													262,000			413,000
Accounts Payable													425,000			400,000
Other Current Liabilities													3,579,000			5,062,000
Total Current Liabilities													301,566,000			264,175,000
Other Noncurrent Liabilities													2,655,000			10,134,000
Total Capitalization and Liabilities													$ 1,682,760,000			$ 1,497,741,000
Common stock, par value (in USD per share)													$ 1.25			$ 1.25
Common Stock, authorized (in shares)													120,000,000			120,000,000
Common Stock, outstanding (in shares)													70,965,622			68,334,860
Cash Dividends Paid to Parent Company										$ 40,800,000	$ 18,200,000	$ 0
[1]	For 2015 and 2014, determined using a combined average statutory tax rate of 40%. For 2013, determined using a combined statutory tax rate of 41%.
[2]	Determined using a combined average statutory tax rate of 40%.
[3]	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2016, $29,454; 2017, $172,558; 2018,$40,667; 2019,$260,783; and 2020, $74,476.
[4]	etermined using a combined statutory tax rate of 41%

Schedule II - Valuation and Q88

Schedule II - Valuation and Qualifying Accounts (Details) - Provision for Uncollectible Accounts [Member] - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period		$ 7,910	$ 5,854	$ 5,924
Charged to Costs and Expenses		14,730	9,519	4,245
Charged to Other Accounts	[1]	(79)	(102)	(41)
Deductions	[2]	12,309	7,361	4,274
Ending Balance		$ 10,252	$ 7,910	$ 5,854
[1]	Recoveries of accounts previously written off and minor adjustments.
[2]	Uncollectible accounts written off.