South Jersey Industries (SJIIU) 10-K 28 Feb 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 15, 2014	Jun. 30, 2013
Entity Information [Line Items]	'	'	'
Entity Registrant Name	'SOUTH JERSEY INDUSTRIES INC	'	'
Entity Central Index Key	'0000091928	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Amendment Flag	'false	'	'
Entity Common Stock, Shares Outstanding	'	32,741,344	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$1,827,264,253

Statements_of_Consolidated_Inc

Statements of Consolidated Income (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Revenues:	'	'	'
Utility	$444,920	$420,818	$405,742
Nonutility	286,501	285,462	422,818
Total Operating Revenues	731,421	706,280	828,560
Cost of Sales - (Excluding depreciation)	'	'	'
- Utility	198,521	187,655	181,158
- Nonutility	270,470	230,147	363,834
Operations	120,205	113,643	100,901
Maintenance	13,136	13,615	13,122
Depreciation	49,637	41,336	35,749
Energy and Other Taxes	9,816	9,986	12,189
Total Operating Expenses	661,785	596,382	706,953
Operating Income	69,636	109,898	121,607
Other Income and Expense	10,979	11,104	15,642
Interest Charges	-18,825	-18,986	-24,078
Income Before Income Taxes	61,790	102,016	113,171
Income Taxes	19,014	-11,479	-22,502
Equity in Earnings (Loss) of Affiliated Companies	1,585	2,239	-810
Income from Continuing Operations	82,389	92,776	89,859
Loss from Discontinued Operations - (Net of tax benefit)	-796	-1,168	-568
Net Income	$81,593	$91,608	$89,291
Basic Earnings per Common Share:	'	'	'
Continuing Operations (in dollars per share)	$2.58	$3.02	$3
Discontinued Operations (in dollars per share)	($0.03)	($0.04)	($0.02)
Basic Earnings Per Common Share (in dollars per share)	$2.55	$2.98	$2.98
Average Shares of Common Stock Outstanding - Basic (in shares)	31,989	30,744	30,000
Diluted Earnings per Common Share:	'	'	'
Continuing Operations (in dollars per share)	$2.57	$3.01	$2.99
Discontinued Operations (in dollars per share)	($0.02)	($0.04)	($0.02)
Diluted Earnings Per Common Share (in dollars per share)	$2.55	$2.97	$2.97
Average Shares of Common Stock Outstanding - Diluted (in shares)	32,046	30,824	30,086

Statements_of_Consolidated_Com

Statements of Consolidated Comprehensive Income (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Statement of Other Comprehensive Income [Abstract]	'		'		'
Net Income	$81,593		$91,608		$89,291
Other Comprehensive Income (Loss), Net of Tax:	'		'		'
Postretirement Liability Adjustment	4,934	[1]	-1,842	[1]	-5,667	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities	103	[1]	500	[1]	-360	[1]
Unrealized Gain (Loss) on Derivatives - Other	265	[1]	-92	[1]	-788	[1]
Other Comprehensive Income (Loss) of Affiliated Companies	5,043	[1]	-1,233	[1]	189	[1]
Other Comprehensive Income (Loss) - Net of Tax	10,345	[1]	-2,667	[1]	-6,626	[1]
Comprehensive Income	$91,938		$88,941		$82,665
Additional Statement Information [Abstract]	'		'		'
Combined statutory tax rate	41.00%		'		'
[1]	Determined using a combined statutory tax rate of 41%.

Statements_of_Consolidated_Cas

Statements of Consolidated Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash Flows from Operating Activities:	'	'	'
Net Income	$81,593	$91,608	$89,291
Loss from Discontinued Operations	796	1,168	568
Income from Continuing Operations	82,389	92,776	89,859
Adjustments to Reconcile Income from Continuing Operations to Net Cash Provided by Operating Activities:	'	'	'
Depreciation and Amortization	64,890	55,089	47,759
Net Unrealized Loss (Gain) on Derivatives - Energy Related	25,823	193	-5,377
Unrealized (Gain) Loss on Derivatives - Other	-2,760	-660	149
Unrealized Loss on Property, Plant and Equipment	0	3,506	0
Provision for Losses on Accounts Receivable	4,245	4,932	2,272
CIP Receivable	21,160	-18,106	-1,289
Deferred Gas Costs - Net of Recoveries	5,473	25,050	-37,343
Deferred SBC Costs - Net of Recoveries	2,393	-4,183	-4,402
Stock-Based Compensation Expense	3,001	2,992	2,511
Deferred and Noncurrent Income Taxes - Net	-21,549	20,306	23,303
Environmental Remediation Costs - Net	-367	-186	-13,608
Gas Plant Cost of Removal	-6,092	-2,133	-1,590
Pension Contribution	-12,700	-25,000	0
Changes in:	'	'	'
Accounts Receivable	-67,825	-59,701	90,407
Inventories	-2,449	13,481	1,905
Prepaid and Accrued Taxes - Net	17,703	-4,635	5,398
Accounts Payable and Other Accrued Liabilities	49,444	18,829	-6,131
Derivatives - Energy Related	1,500	306	740
Other Assets and Liabilities	-3,769	-4,211	-2,245
Cash Flows from Discontinued Operations	-975	-819	-961
Net Cash Provided by Operating Activities	159,535	117,826	191,357
Cash Flows from Investing Activities:	'	'	'
Capital Expenditures	-316,644	-253,845	-193,119
Proceeds from Sale of Property, Plant and Equipment	0	29	3,500
Net (Purchase of) Proceeds from Sale of Restricted Investments in Margin Accounts	-25,164	755	-10,269
Investment in Long-Term Receivables	-7,182	-6,243	-4,926
Proceeds from Long-Term Receivables	5,764	8,182	6,312
Purchase of Company Owned Life Insurance	-5,149	-4,547	-4,628
Investment in Affiliate	-2,973	-39,431	-23,043
Return on Investment in Affiliate	0	0	2,339
Advances on Notes Receivable - Affiliate	-19,349	-67,943	-41,612
Repayment of Notes Receivable - Affiliate	124,946	13,402	47,694
Other	-41	-6,276	-6,423
Net Cash Used in Investing Activities	-245,792	-355,917	-224,175
Cash Flows from Financing Activities:	'	'	'
Net Borrowings from Short-Term Credit Facilities	65,000	17,500	70,714
Proceeds from Issuance of Long-Term Debt	50,000	235,000	0
Payments for Issuance of Long-Term Debt	-411	-1,788	-43
Principal Repayments of Long-Term Debt	-25,000	-35,000	-25,000
Premium for Early Retirement of Debt	0	-700	0
Dividends on Common Stock	-57,679	-50,942	-44,975
Proceeds from Sale of Common Stock	54,028	70,241	13,436
Proceeds from Finance Obligation	0	0	23,482
Other	-501	880	379
Net Cash Provided by Financing Activities	85,437	235,191	37,993
Net (Decrease) Increase in Cash and Cash Equivalents	-820	-2,900	5,175
Cash and Cash Equivalents at Beginning of Period	4,638	7,538	2,363
Cash and Cash Equivalents at End of Period	3,818	4,638	7,538
Cash paid during the year for:	'	'	'
Interest (Net of Amounts Capitalized)	18,584	18,442	25,303
Income Taxes (Net of Refunds)	-12,387	218	-9,861
Supplemental Disclosures of Non-Cash Investing Activities	'	'	'
Capital Expenditures acquired on account but unpaid as of year-end	44,874	34,086	20,457
Reclass from Notes Receivable Affiliate to Investment in Affiliates	0	2,952	5,351
Notes Receivable from Affiliate Exchanged for Notes Receivable from a Third Party	7,882	0	0
Notes Receivable Affiliate Exchanged for Accounts Receivable	$0	$0	$1,783

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Property, Plant and Equipment:	'		'
Utility Plant, at original cost	$1,816,804		$1,658,790
Accumulated Depreciation	-392,029		-373,199
Nonutility Property and Equipment, at cost	486,332		328,638
Accumulated Depreciation	-52,009		-36,208
Property, Plant and Equipment - Net	1,859,098		1,578,021
Investments:	'		'
Available-for-Sale Securities	8,716		7,538
Restricted	43,115		17,903
Investment in Affiliates	78,273		75,825
Total Investments	130,104		101,266
Current Assets:	'		'
Cash and Cash Equivalents	3,818		4,638
Accounts Receivable	253,566		195,293
Unbilled Revenues	47,594		40,938
Provision for Uncollectibles	-5,854		-5,924
Notes Receivable - Affiliate	8,908		39,495
Natural Gas in Storage, average cost	57,786		55,517
Materials and Supplies, average cost	2,798		2,618
Deferred Income Taxes - Net	30,609		0
Prepaid Taxes	9,431		26,187
Derivatives - Energy Related Assets	56,327		24,242
Other Prepayments and Current Assets	17,915		11,833
Total Current Assets	482,898		394,837
Regulatory and Other Noncurrent Assets:	'		'
Regulatory Assets	296,081		352,656
Derivatives - Energy Related Assets	26,451		12,297
Unamortized Debt Issuance Costs	7,803		8,226
Notes Receivable - Affiliate	39,907		117,188
Contract Receivables	14,595		13,985
Notes Receivable	7,882		0
Other	60,036		52,964
Total Regulatory and Other Noncurrent Assets	452,755		557,316
Total Assets	2,924,855		2,631,440
Common Stock: Par Value $1.25 per share; Authorized 60,000,000 shares; Outstanding Shares: 32,715,042 (2013) and 31,653,262 (2012)	'		'
Balance at Beginning of Year	39,567		37,765
Common Stock Issued or Granted Under Stock Plans	1,327		1,802
Balance at End of Year	40,894		39,567
Premium on Common Stock	401,011		345,807
Treasury Stock (at par)	-186		-182
Accumulated Other Comprehensive Loss	-20,760	[1]	-31,105	[1]
Retained Earnings	406,041		382,127
Total Equity	827,000		736,214
Long-Term Debt	680,400	[2]	601,400	[2]
Total Capitalization	1,507,400		1,337,614
Current Liabilities:	'		'
Notes Payable	353,900		338,900
Current Portion of Long-Term Debt	21,000	[2]	25,000	[2]
Accounts Payable	259,757		193,331
Customer Deposits and Credit Balances	15,546		17,757
Environmental Remediation Costs	16,695		21,026
Taxes Accrued	3,234		2,156
Derivatives - Energy Related Liabilities	77,993		23,828
Deferred Income Taxes - Net	0		10,812
Interest Accrued	6,363		6,635
Pension Benefits	1,275		1,272
Other Current Liabilities	9,210		11,127
Total Current Liabilities	764,973		651,844
Deferred Credits and Other Noncurrent Liabilities:	'		'
Deferred Income Taxes - Net	319,368		289,489
Investment Tax Credits	360		618
Pension and Other Postretirement Benefits	57,370		105,168
Environmental Remediation Costs	106,734		91,072
Asset Retirement Obligations	41,687		39,385
Derivatives - Energy Related Liabilities	22,131		5,403
Derivatives - Other	6,676		13,462
Regulatory Liabilities	60,949		56,517
Finance Obligation	20,656		21,646
Other	16,551		19,222
Total Deferred Credits and Other Noncurrent Liabilities	652,482		641,982
Commitments and Contingencies (Note 15)	'		'
Total Capitalization and Liabilities	$2,924,855		$2,631,440
[1]	Determined using a combined statutory tax rate of 41%.
[2]	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Statement of Financial Position [Abstract]	'	'	'	'
Common stock, par value (in dollars per share)	$1.25	$1.25	'	'
Common stock, authorized	60,000,000	60,000,000	'	'
Common stock, outstanding	32,715,042	31,653,262	30,212,453	29,872,825

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Equity and Comprehensive Income (USD $)		Total	Common Stock [Member]	Premium on Common Stock [Member]	Treasury Stock [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]
In Thousands, unless otherwise specified
Balance at Dec. 31, 2010		$570,097	$37,341	$257,274	($179)	($21,812)	$297,473
Increase (Decrease) in Stockholders' Equity [Roll Forward]		'	'	'	'	'	'
Net Income		89,291	'	'	'	'	89,291
Other Comprehensive (Loss) Income, Net of Tax	[1]	-6,626	'	'	'	-6,626	'
Common Stock Issued or Granted Under Stock Plans		16,327	424	16,029	-14	'	-112
Cash Dividends Declared - Common Stock		-44,975	'	'	'	'	-44,975
Balance at Dec. 31, 2011		624,114	37,765	273,303	-193	-28,438	341,677
Increase (Decrease) in Stockholders' Equity [Roll Forward]		'	'	'	'	'	'
Net Income		91,608	'	'	'	'	91,608
Other Comprehensive (Loss) Income, Net of Tax	[1]	-2,667	'	'	'	-2,667	'
Common Stock Issued or Granted Under Stock Plans		74,101	1,802	72,504	11	'	-216
Cash Dividends Declared - Common Stock		-50,942	'	'	'	'	-50,942
Balance at Dec. 31, 2012		736,214	39,567	345,807	-182	-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	1,327	55,204	-4	'	'
Cash Dividends Declared - Common Stock		-57,679	'	'	'	'	-57,679
Additional Statement Information [Abstract]		'	'	'	'	'	'
Combined statutory tax rate		41.00%	'	'	'	'	'
Balance at Dec. 31, 2013		$827,000	$40,894	$401,011	($186)	($20,760)	$406,041
[1]	Determined using a combined statutory tax rate of 41%.

Consolidated_Statements_of_Cha1

Consolidated Statements of Changes in Equity and Comprehensive Income (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Balance at January 1	($31,105)	[1]	'		'
Changes During Year	10,345	[1]	-2,667	[1]	-6,626	[1]
Balance at December 31	-20,760	[1]	-31,105	[1]	'
Postretirement Liability Adjustment [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Balance at January 1	-23,437	[1]	-21,595	[1]	-15,928	[1]
Changes During Year	4,934	[1]	-1,842	[1]	-5,667	[1]
Balance at December 31	-18,503	[1]	-23,437	[1]	-21,595	[1]
Unrealized Gain (Loss) on Derivatives-Other [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Balance at January 1	-2,962	[1]	-2,870	[1]	-2,082	[1]
Changes During Year	265	[1]	-92	[1]	-788	[1]
Balance at December 31	-2,697	[1]	-2,962	[1]	-2,870	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Balance at January 1	294	[1]	-206	[1]	154	[1]
Changes During Year	103	[1]	500	[1]	-360	[1]
Balance at December 31	397	[1]	294	[1]	-206	[1]
Other Comprehensive Income (Loss) of Affiliated Companies [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Balance at January 1	-5,000	[1]	-3,767	[1]	-3,956	[1]
Changes During Year	5,043	[1]	-1,233	[1]	189	[1]
Balance at December 31	43	[1]	-5,000	[1]	-3,767	[1]
Accumulated Other Comprehensive Loss [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Balance at January 1	-31,105	[1]	-28,438	[1]	-21,812	[1]
Changes During Year	10,345	[1]	-2,667	[1]	-6,626	[1]
Balance at December 31	($20,760)	[1]	($31,105)	[1]	($28,438)	[1]
[1]	Determined using a combined statutory tax rate of 41%.

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2013
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 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.
	▪	Marina Energy, LLC (Marina) develops and operates on-site energy-related projects.
	▪	South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets on a wholesale basis in the mid-Atlantic, Appalachian and southern states.
	▪	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.
	▪	South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.
	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 and operating results at the dates and for the periods presented.
	Certain reclassifications have been made to the prior periods regulatory assets disclosure to conform to the current period presentation. The deferred pipeline integrity cost previously included in "Other Regulatory Assets" was reclassified to the line item "Pipeline Integrity Cost" in the regulatory asset table disclosed in Note 11.
	Certain reclassifications have been made to the prior period segment disclosures to conform to the current period presentation. In all periods presented, net receivables between the Discontinued Operations segment and the Corporate and Services segment have been reclassified in the Identifiable Assets Segment disclosure in Note 8.
	EQUITY INVESTMENTS - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. SJI, through wholly owned subsidiaries, holds significant variable interests in several companies but is not the primary beneficiary.  Consequently, these investments are accounted for under the equity method. In the event that losses and/or distributions from these equity method investments exceed the carrying value, and the Company is obligated to provide additional financial support, the excess will be recorded as either a current or non-current liability on the consolidated balance sheets. We include the operations of these affiliated companies on a pre-tax basis in the statements of consolidated income under Equity in Earnings (Loss) of Affiliated Companies (See Note 3).  An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary.  No impairment losses were recorded on Investments during 2013, 2012 or 2011.
	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 FASB ASC Topic 980 -”Regulated Operations.”  In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 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. 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). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both utility revenue and cost of sales and totaled $5.2 million, $6.0 million, and $8.0 million in 2013, 2012 and 2011, respectively. TEFA is subject to a planned phase-out which decreased the assessment in increments of 25.0% in 2012 and 2013, and is eliminated after December 31, 2013.
	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):
			2013		2012
	AROs as of January 1,		39,385		29,430
	Accretion		1,530		1,872
	Additions		743		1,438
	Settlements		(1,630	)	(1,603	)
	Revisions in Estimated Cash Flows (A)		1,659		8,248
	ARO's as of December 31,		41,687		39,385
	(A) The revision in estimated cash flows in 2013 reflects an increase in the inflation rate used to determine the ARO settlement amount. In 2012, the revision in estimated cash flows reflected increases in the contractual cost as well as changes in the discount rates used to determine the 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 2.3% in 2013, 2.4% in 2012, and 2.3% in 2011. 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 - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in its last base rate proceeding (see Note 10). Marina capitalizes interest on construction 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 consolidated statements of income.  The amount of interest capitalized by SJI for the years ended December 31, 2013, 2012 and 2011 was $8.7 million, $6.5 million and $1.2 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. During the year ended December 31, 2012, the Company recorded an impairment charge of $2.4 million within Operating Expenses on the consolidated statement of income due to a reduction in the expected cash flows to be received from a solar generating facility within the on-site energy production segment. The Company also recorded a $1.1 million impairment charge during the year ended December 31, 2012 related to certain shallow wells in the Marcellus region as discussed under “Gas Exploration and Development”. For the years ended December 31, 2013 and 2011, 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. In July 2012, hedge accounting was 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. During the year ended December 31, 2012, the Company recorded $1.1 million of impairment charges within Other Income and Expense on the consolidated statement of income due to a reduction in the expected cash flows to be received from certain shallow wells in the Marcellus region. No impairment charges were recorded during the years ended December 31, 2013 and 2011. As of December 31, 2013 and 2012, $8.9 million and $9.0 million, respectively, related to interests in proved and unproved properties in Pennsylvania, net of amortization, are 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, 2013 and 2012, SJI held 148,890 and 145,414 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 the non-regulated entities 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.
	NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2013, 2012 or 2011 had, or is expected to have, a material impact on the consolidated financial statements.
	In January 2012, the FASB issued ASU 2011-11, Enhanced Disclosure Requirements Concerning Offsetting of Financial Assets and Financial Liabilities. This ASU amends ASC 210-20 to add disclosure requirements in respect of the offsetting of financial assets and financial liabilities. In February 2013, the FASB issued ASU 2013-01 Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which amends and clarifies the scope of the balance sheet offsetting disclosures required through ASU 2011-11. The new guidance is effective for fiscal years beginning on or after January 1, 2013. The adoption of this guidance modified the disclosures around derivative instruments, but did not have an impact on the Company's financial statement results.
	In February 2013, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.
	In July 2013, the FASB issued ASU 2013-11, Balance Sheet Presentation of an Unrecognized Income Tax Benefit for a Net Operating Loss or Tax Credit Carryforward. This ASU provides that a liability related to an unrecognized tax benefit should be offset against a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. Management does not anticipate that the adoption of this guidance will have an impact on the Company's financial statement results.

STOCKBASED_COMPENSATION_PLAN

STOCK-BASED COMPENSATION PLAN	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
STOCK-BASED COMPENSATION PLAN	'
	STOCK-BASED COMPENSATION PLAN:
	Under the Amended and Restated 1997 Stock-Based Compensation Plan, no more than 2,000,000 shares in the aggregate may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. The plan will terminate on January 26, 2015, unless terminated earlier by the Board of Directors. No options were granted or outstanding during the years ended December 31, 2013, 2012 and 2011.   No stock appreciation rights have been issued under the plan. During the years ended December 31, 2013, 2012 and 2011, SJI granted 56,464, 40,955 and 40,711 restricted shares to Officers and other key employees, respectively.  These 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 150% of the original share units granted.
	Grants containing market-based performance targets have been issued in each of the last three years and 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.
	Beginning with 2012, grants containing earnings-based targets have also been issued. These new grants are based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance. As EPS-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 goals.
	SJI granted 12,285, 9,904 and 12,220 restricted shares to Directors in 2013, 2012 and 2011, respectively.  Shares issued to Directors in 2011 vest over a three-year service period and contain no performance conditions. Shares issued to Directors in 2013 and 2012 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, 2013 and the assumptions used to estimate the fair value of the awards:
		Grant Date		Shares Outstanding			Fair Value Per Share				Expected Volatility		Risk-Free Interest Rate
	Officers & Key Employees -	Jan. 2012 - TSR		19,810			$	51.23			22.5	%	0.43	%
		Jan. 2012 - EPS		19,810			$	56.93			N/A		N/A
		Jan. 2013 - TSR		27,286			$	44.38			21.1	%	0.4	%
		Jan. 2013 - EPS		27,286			$	51.18			N/A		N/A
	Directors -	Jan. 2011		7,332			$	52.94			—		—
		Jan. 2013		12,285			$	51.74			—		—
	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, which are reinvested 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):
		2013				2012				2011
	Officers & Key Employees	$	2,236			$	2,096			$	1,852
	Directors	765				896				658
	Total Cost	3,001				2,992				2,510
	Capitalized	(237		)		(231		)		(218		)
	Net Expense	$	2,764			$	2,761			$	2,292
	As of December 31, 2013, there was $2.5 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 1.7 years.
	The following table summarizes information regarding restricted stock award activity during 2013, excluding accrued dividend equivalents:
		Officers & Other Key Employees			Directors			Weighted
								Average
								Fair Value
	Nonvested Shares Outstanding, January 1, 2013	81,005			27,688			$	51.29
	Granted	56,464			12,285			$	48.49
	Vested*	(39,720	)		(20,356	)		$	49.2
	Cancelled/Forfeited	(3,557	)		—			$	50.28
	Nonvested Shares Outstanding, December 31, 2013	94,192			19,617			$	50.73
	*Performance targets during the three-year vesting period were not attained for the January 2011 grant. As a result, no shares will be awarded in 2014.
	During the years ended December 31, 2013, 2012 and 2011, SJI awarded 66,077 shares to its Officers and other key employees at a market value of $3.3 million, 33,322 shares at a market value of $1.9 million, and 69,271 shares at a market value of $3.7 million, respectively. Also, during the years ended December 31, 2013, 2012 and 2011, SJI awarded 12,285, 9,904 and 12,220 shares to its Directors at a market value of $0.6 million for each year. The Company has a policy of issuing new shares to satisfy its obligations under these 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.

DISCONTINUED_OPERATIONS_AND_AF

DISCONTINUED OPERATIONS AND AFFILIATIONS	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
DISCONTINUED OPERATIONS AND AFFILATIONS	'
	DISCONTINUED OPERATIONS AND AFFILATIONS:
	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):
		2013			2012			2011
	Loss before Income Taxes:
	Sand Mining	$	(406	)	$	(1,396	)	$	(169	)
	Fuel Oil	(816		)	(401		)	(701		)
	Income Tax Benefits	426			629			302
	Loss from Discontinued Operations — Net	$	(796	)	$	(1,168	)	$	(568	)
	Earnings Per Common Share from
	Discontinued Operations — Net:
	Basic	$	(0.03	)	$	(0.04	)	$	(0.02	)
	Diluted	$	(0.02	)	$	(0.04	)	$	(0.02	)
	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.
	In April 2012, Energenic acquired The Energy Network, LLC, a holding company for the Hartford Steam Company, TEN Companies and CNE Power I, LLC. In conjunction with this acquisition, Marina provided $35.4 million of advances to Energenic, which were repaid by Energenic during the second quarter of 2013 when permanent financing was obtained.
	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.
	LVE Energy Partners, LLC (LVE) - In March 2013, substantially all of the assets of Marina's joint venture, LVE, an entity in which Marina has a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.9 million. LVE was dissolved prior to December 31, 2013. See Note 15.
	During 2013, 2012 and 2011, the Company made investments in, and provided net advances to, unconsolidated affiliates of $9.6 million, $94.0 million and $14.6 million, respectively. These amounts do not include the cash proceeds from LVE and the repayment of the advances to Energenic as discussed above. The purpose of these investments and advances was to cover certain project-related costs of affiliates.   As of December 31, 2013 and 2012, the outstanding balance on these Notes Receivable – Affiliate was $48.8 million and $156.7 million, respectively. These notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025.
	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, 2013, the Company had a net asset of approximately $78.3 million included in Investment in Affiliates and Other Noncurrent Liabilities 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, 2013 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $127.1 million and the guarantees discussed in Note 15.
	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):
		2013			2012
	Current assets		$	57,725		$	57,711
	Noncurrent assets		$	494,933		$	759,996
	Current liabilities		$	60,355		$	211,628
	Noncurrent liabilities		$	341,548		$	460,560
		2013			2012			2011
	Revenues		$	178,026		$	148,009		$	95,647
	Cost of sales		$	91,228		$	71,141		$	64,181
	Income from continuing operations		$	6,229		$	5,795		$	1,522
	Net Income		$	6,229		$	5,795		$	1,522

INCOME_TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2013
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):
		2013			2012			2011
	Tax at Statutory Rate	$	22,181		$	36,490		$	39,326
	Increase (Decrease) Resulting from:
	State Income Taxes	971			5,857			6,763
	ESOP	(1,176		)	(1,141		)	(1,063		)
	Amortization of Investment Tax Credits - Utility	(258		)	(287		)	(302		)
	Amortization of Flowthrough Depreciation	—			—			526
	AFUDC	(916		)	(1,048		)	(729		)
	Investment and Other Tax Credits	(38,179		)	(26,574		)	(21,927		)
	Other - Net	(1,637		)	(1,818		)	(92		)
	Income Taxes:
	Continuing Operations	(19,014		)	11,479			22,502
	Discontinued Operations	(426		)	(629		)	(302		)
	Net Income Taxes	$	(19,440	)	$	10,850		$	22,200
	The provision for Income Taxes is comprised of the following (in thousands):
		2013			2012			2011
	Current:
	Federal	$	(273	)	$	(8,761	)	$	(844	)
	State	3,066			221			345
	Total Current	2,793			(8,540		)	(499		)
	Deferred:
	Federal	(19,978		)	11,515			13,244
	State	(1,571		)	8,791			10,059
	Total Deferred	(21,549		)	20,306			23,303
	Investment Tax Credit - Utility	(258		)	(287		)	(302		)
	Income Taxes:
	Continuing Operations	(19,014		)	11,479			22,502
	Discontinued Operations	(426		)	(629		)	(302		)
	Net Income Taxes	$	(19,440	)	$	10,850		$	22,200
	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 liabilities (assets) at December 31 (in thousands):
		2013			2012
	Current:
	Net Operating Loss Carryforward	$	(26,800	)	$	(2,586	)
	Derivatives / Unrealized Gain	(8,608		)	257
	Conservation Incentive Program	4,631			13,942
	Budget Billing - Customer Accounts	1,152			1,033
	Provision for Uncollectibles	(1,994		)	(1,883		)
	Other	1,010			49
	Current Deferred Tax (Asset) Liability  - Net	$	(30,609	)	$	10,812
	Noncurrent:
	Book versus Tax Basis of Property	$	476,039		$	395,322
	Deferred Gas Costs - Net	1,330			3,325
	Environmental	13,017			16,006
	Deferred Regulatory Costs	13,665			15,374
	Deferred State Tax	(17,949		)	(17,924		)
	Investment Tax Credit Basis Gross-Up	(185		)	(318		)
	Deferred Pension & Other Post Retirement Benefits	24,218			39,174
	Pension & Other Post Retirement Benefits	(17,777		)	(33,739		)
	Deferred Revenues	(9,593		)	(9,367		)
	Derivatives / Unrealized  Gain	2,149			(82		)
	Net Operating Loss Carryforward	(90,818		)	(79,217		)
	Investment and Other Tax Credits	(117,726		)	(71,547		)
	Equity In Loss Of Affiliated Companies	37,764			30,707
	Other	5,234			1,775
	Noncurrent Deferred Tax Liability - Net	$	319,368		$	289,489
	As of December 31, 2013, SJI has federal net operating loss carryforwards of $317.7 million and state net operating loss carryforwards of $105.4 million. Of these totals, $163.9 million and $45.9 million of the federal and state net operating loss carryforwards, respectively, will expire in 2031, $43.7 million and $19.4 million of the federal and state net operating loss carryforwards, respectively, will expire in 2032 and $110.1 million and $40.1 million of the federal and state net operating loss carryforwards, respectively, will expire in 2033. SJI also has investment tax credit carryforwards of $116.5 million, of which $11.6 million will expire in 2030, $26.6 million will expire in 2031,$32.1 million will expire in 2032 and $46.2 million will expire in 2033. SJI has $1.2 million of federal alternative minimum tax credits which have no expiration date. 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, 2013, 2012, and 2011 were $0.5 million, $0.5 million, and $0.7 million, respectively, which excludes $0.6 million, $0.6 million, and $0.7 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):
		2013			2012			2011
	Balance at January 1,	$	503		$	736		$	793
Increase as a result of tax positions taken in prior years	44			108			119
Decrease due to a lapse in the statute of limitations	—			(341		)	(90		)
Settlements	—			—			(86		)
Balance at December 31,	$	547		$	503		$	736
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 2013, 2012 or 2011. There have been no significant changes to the unrecognized tax benefits during 2013, 2012 or 2011 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 and state income tax returns from 2009 forward are open and subject to examination.

PREFERRED_STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2013
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, 2013
Common Stock [Abstract]	'
COMMON STOCK	'
	COMMON STOCK:
	The following shares were issued and outstanding at December 31:
		2013	2012	2011
	Beginning of Year	31,653,262	30,212,453	29,872,825
	New Issues During Year:
	Dividend Reinvestment Plan	983,417	1,397,583	259,359
	Stock-Based Compensation Plan	78,363	43,226	80,269
	End of Year	32,715,042	31,653,262	30,212,453
	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, 2013, 2012, and 2011 of approximately $55.2 million, $72.5 million, and $16.0 million, respectively, 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 57,760, 79,475, and 86,031 shares for the years ended December 31, 2013, 2012 and 2011, respectively. These shares relate to SJI’s restricted stock as discussed in Note 2.
	DIVIDENDS PER SHARE - Dividends per share were $1.80, $1.65 and $1.50 for the years ended December 31, 2013, 2012 and 2011, 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 $54.0 million and $70.2 million of equity capital through the DRP during the years ended December 31, 2013 and 2012, respectively.

FINANCIAL_INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
Financial Instruments, Owned, at Fair Value [Abstract]	'
FINANCIAL INSTRUMENTS	'
	FINANCIAL INSTRUMENTS:
	RESTRICTED INVESTMENTS — In accordance with the terms of certain Marina and SJG loan agreements, unused proceeds are required to be escrowed pending approval of construction expenditures. As of both December 31, 2013 and 2012, the escrowed proceeds, including interest earned, totaled $1.3 million.
	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, 2013 and 2012, the balances in these accounts totaled $41.8 million and $16.6 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at December 31, 2013 and 2012, which would be included in Level 1 of the fair value hierarchy (See Note 17 - Fair Value of Financial Assets and Financial Liabilities).
	LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources.  The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest.  The carrying amounts of such loans were $15.0 million and $13.6 million as of December 31, 2013 and 2012, 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, 2013 and 2012.  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, 2013 and 2012, which would be included in Level 2 of the fair value hierarchy (See Note 17 - Fair Value of Financial Assets and Financial Liabilities).
	CREDIT RISK - As of December 31, 2013, approximately $28.1 million or 33.9% of current and noncurrent Derivatives–Energy Related Assets are with two counterparties. One of these counterparties 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), 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 continues to be considered the owner of the facility for accounting purposes under ASC Topic 360 Property, Plant and Equipment. As a result, the transaction is being accounted for as a financing arrangement under ASC Topic 840 Leases and therefore the Company has included costs to construct the facility within Nonutility Property, Plant and Equipment on the consolidated balance sheets of $23.7 million and $23.6 million as of December 31, 2013 and 2012, respectively. 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. The costs to construct the facility and the repayments of the construction loan are amortized over the term of the energy services agreement. The impact on the consolidated statements of income is not significant. As a result, the Company recorded $20.7 million and $21.6 million, net of amortization, within Finance Obligation on the consolidated balance sheets at December 31, 2013 and 2012, respectively.
	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, 2013 and 2012, 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, 2013 and 2012, were $713.2 million and $682.3 million, respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of December 31, 2013 and 2012, was $701.4 million and $626.4 million, respectively.
	OTHER FINANCIAL INSTRUMENTS – The carrying amounts of SJI’s other financial instruments approximate their fair values at December 31, 2013 and 2012.

SEGMENTS_OF_BUSINESS

SEGMENTS OF BUSINESS	12 Months Ended
	Dec. 31, 2013
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. Gas Utility Operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers. Wholesale Energy Operations include SJRG’s and SJEX's activities. 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. 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 Retail Energy Operations caption includes Retail Gas and Other, Retail Electric, 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):
		2013			2012			2011
	Operating Revenues:
	Gas Utility Operations	$	446,480		$	421,874		$	412,449
	Wholesale Energy Operations	831			17,429			68,370
	Retail Energy Operations:
	Retail Gas and Other Operations	107,748			80,486			100,977
	Retail Electric Operations	128,932			144,197			206,422
	On-Site Energy Production	43,551			38,308			39,919
	Appliance Service Operations	13,723			13,646			17,056
	Subtotal Retail Energy Operations	293,954			276,637			364,374
	Corporate & Services	31,286			29,318			25,325
	Subtotal	772,551			745,258			870,518
	Intersegment Sales	(41,130		)	(38,978		)	(41,958		)
	Total Operating Revenues	$	731,421		$	706,280		$	828,560
		2013			2012			2011
	Operating Income:
	Gas Utility Operations	$	105,822		$	101,762		$	102,663
	Wholesale Energy Operations	(37,720		)	(2,142		)	16,225
	Retail Energy Operations:
	Retail Gas and Other Operations	278			(1,204		)	478
	Retail Electric Operations	(98		)	12,683			1,755
	On-Site Energy Production	(2,011		)	(1,696		)	2,254
	Appliance Service Operations	2,995			(225		)	(1,539		)
	Subtotal Retail Energy Operations	1,164			9,558			2,948
	Corporate and Services	370			720			(229		)
	Total Operating Income	$	69,636		$	109,898		$	121,607
	Depreciation and Amortization:
	Gas Utility Operations	$	48,261		$	44,171		$	41,959
	Wholesale Energy Operations	206			229			253
	Retail Energy Operations:
	Retail Gas and Other Operations	93			78			33
	On-Site Energy Production	15,192			9,604			4,527
	Appliance Service Operations	261			308			322
	Subtotal Retail Energy Operations	15,546			9,990			4,882
	Corporate and Services	877			699			665
	Total Depreciation and Amortization	$	64,890		$	55,089		$	47,759
	Interest Charges:
	Gas Utility Operations	$	12,550		$	12,427		$	18,922
	Wholesale Energy Operations	417			229			54
	Retail Energy Operations:
	Retail Gas and Other Operations	280			139			186
	On-Site Energy Production	4,480			4,936			5,436
	Subtotal Retail Energy Operations	4,760			5,075			5,622
	Corporate and Services	6,004			4,219			2,648
	Subtotal	23,731			21,950			27,246
	Intersegment Borrowings	(4,906		)	(2,964		)	(3,168		)
	Total Interest Charges	$	18,825		$	18,986		$	24,078
	Income Taxes:
	Gas Utility Operations	$	34,833		$	33,711		$	34,281
	Wholesale Energy Operations	(15,070		)	(907		)	7,517
	Retail Energy Operations:
	Retail Gas and Other Operations	434			(144		)	511
	Retail Electric Operations	(40		)	5,181			717
	On-Site Energy Production	(40,755		)	(26,811		)	(22,258		)
	Appliance Service Operations	1,237			(75		)	1,480
	Subtotal Retail Energy Operations	(39,124		)	(21,849		)	(19,550		)
	Corporate and Services	347			524			254
	Total Income Taxes	$	(19,014	)	$	11,479		$	22,502
		2013			2012			2011
	Property Additions:
Gas Utility Operations	$	173,099		$	156,990		$	141,918
Wholesale Energy Operations	50			23			83
Retail Energy Operations:
Retail Gas and Other Operations	702			177			22
On-Site Energy Production	151,592			107,993			57,093
Appliance Service Operations	—			34			254
Subtotal Retail Energy Operations	152,294			108,204			57,369
Corporate and Services	3,061			4,308			605
Total Property Additions	$	328,504		$	269,525		$	199,975
	2013			2012
Identifiable Assets (See Note 1):
Gas Utility Operations	$	1,909,126		$	1,786,459
Wholesale Energy Operations	331,182			204,358
Retail Energy Operations:
Retail Gas and Other Operations	50,384			39,481
Retail Electric Operations	25,496			21,919
On-Site Energy Production	576,315			543,416
Appliance Service Operations	1,812			3,244
Subtotal Retail Energy Operations	654,007			608,060
Discontinued Operations	1,068			2,290
Corporate and Services	406,245			334,798
Intersegment Assets	(376,773		)	(304,525		)
Total Identifiable Assets	$	2,924,855		$	2,631,440

LEASES

LEASES	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
LEASES	'
	LEASES:
	The Company 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, 2013 and 2012 the carrying costs of this property and equipment under operating lease was $81.8 million and $72.3 million, respectively, (net of accumulated depreciation of $22.7 million and $20.0 million, respectively) and is included in Nonutility Property and Equipment in the consolidated balance sheets.
	Minimum future rentals to be received on non-cancelable leases of thermal energy generating property and equipment as of December 31, 2013 for each of the next five years and in the aggregate are (in thousands):
	Year ended December 31,
	2014	$	5,396
	2015	5,396
	2016	5,396
	2017	5,396
	2018	5,396
	Thereafter	45,418
	Total minimum future rentals	$	72,398
	Minimum future rentals do not include additional amounts to be received based on actual use of the leased property.

RATES_AND_REGULATORY_ACTIONS

RATES AND REGULATORY ACTIONS	12 Months Ended
	Dec. 31, 2013
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 will be 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 November 2013, SJG filed a base rate case with the BPU to increase its base rates to obtain a certain level of return on its capital investments. SJG expects the base rate case to be concluded during 2014. Other than the CIRT items discussed above, SJG has not sought a base rate increase from the BPU since the implementation of its base rate case approved in September 2010.
	RATE MECHANISMS - SJG's tariff, a schedule detailing the terms, conditions and rate information applicable to the 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 was approved by the BPU in January 2003, and 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 though 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:
	.
	•	March 2011 - SJG credited the accounts of its periodic BGSS customers with refunds totaling $21.1 million due to gas costs that were lower than projected during the winter season.
	•	June 2011 - SJG filed its annual BGSS filing with the BPU requesting a $10.6 million, or 2.9%, reduction in gas cost recoveries commencing on October 1, 2011.
	•	September 2011 - The BPU issued an Order finalizing the 2010-2011 provisional BGSS rate and approved, on a provisional basis, SJG's request for a $10.6 million or 2.9% reduction in gas cost recoveries.
	•	December 2011 - SJG credited the accounts of its periodic BGSS customers with refunds totaling $18.7 million due to gas costs that were lower than projections.
	•	May 2012 - The BPU issued an Order finalizing the 2011-2012 provisional BGSS rates.
	•	June 2012 - SJG filed its annual BGSS filing with the BPU requesting a $27.0 million, or 8.8%, reduction in gas cost recoveries commencing on October 1, 2012.
	•	September 2012 - The BPU issued an Order approving, on a provisional basis, SJG's request for a 27.0 million, or 8.8%, reduction in gas cost recoveries.
	•	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.
	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.  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:
	•	June 2011 - SJG made its annual CIP filing with the BPU requesting recovery of $2.5 million, which includes a $2.7 million credit to customers for the current 2011-2012 CIP year and prior year carryovers of $5.2 million. The CIP credit of $2.7 million includes $1.3 million non-weather related credits and $1.4 million weather related credits.
	•	September 2011 - The BPU issued an Order finalizing the 2010-2011 provisional CIP rates and also approved, on a provisional basis, the 2011-2012 CIP rates filed in June 2011, effective October 1, 2011.
	•	May 2012 - The BPU issued an Order finalizing the 2011-2012 provisional CIP rates.
	•	June 2012 - SJG made its annual CIP filing with the BPU requesting recovery of $28.0 million, which includes a $8.4 million non-weather related recovery and a $19.6 million weather related recovery.
	•	September 2012 - The BPU issued an Order approving, on a provisional basis, the 2012-2013 CIP rates filed in June 2012, effective October 1, 2012.
	•	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.
	Capital Investment Recovery Tracker (CIRT) - In January 2009, SJG made a filing with the BPU requesting approval for an accelerated infrastructure investment program.  The purpose of the CIRT was to accelerate $103.0 million of capital expenditures from five years to two years.  The petition requested that the Company be allowed to earn a return of, and a return on, its investment.  Under the CIRT, 2009 spending was projected to be $70.5 million and 2010 spending was projected to be $32.5 million.  In September 2010, the BPU authorized $81.3 million of CIRT-related expenditures to be rolled into rate base and also authorized that the remaining balance of CIRT-related expenditures continue to be recovered.  These remaining expenditures were reviewed and rolled into rate base during Phase II of the base rate case. On a monthly basis during the CIRT year, SJG recorded adjustments to earnings based on actual CIRT program expenditures, as incurred.  Annually, SJG made filings with the BPU for review and approval of expenditures recorded under the CIRT.
	Regulatory actions regarding the CIRT were as follows:
	•	March 2011 - The BPU approved a CIRT II program allowing SJG to accelerate an additional $60.3 million of capital spending into 2011 and 2012. Under CIRT II, SJG continues to earn a return on investment as the capital is spent, as it did under the original CIRT. The return of investment begins when the investments are rolled into rate base. As such, SJG is permitted to earn a return on CIRT II investments until the roll in is approved and recovery commences.
	•	June 2011 - SJG filed a petition with the BPU requesting the recovery of a portion of CIRT II investments via a roll-in to rate base, and requested to increase the base rates by 0.5%.
	•	October 2011 - SJG filed a petition with the BPU requesting to modify and extend the CIRT II program. The petition requested an additional incremental investment of $40.0 million in 2012 and $50.0 million in 2013.
	•	May 2012 - The BPU approved a modification and extension of the CIRT II program (CIRT III), allowing SJG to accelerate an incremental $35.0 million of capital spending through December 2012.
	•	October 2012 - SJG filed a petition requesting a $13.2 million increase in annual revenues by rolling $110.6 million of CIRT I, II and III investments into base rates.
	•	September 2013 - The BPU approved the base rate roll in of the CIRT I, II and III program investments effective October 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 Accelerated Infrastructure Replacement Program (AIRP) to replace the annual CIRT programs. In February 2013, the BPU issued a Board 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 Board Order, AIRP investments are to be reviewed and included in rate base in future base rate proceedings.
	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. This petition is currently pending.
	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 is permitted to invest $17.0 million over two years in energy efficiency measures to be installed in customer homes and businesses. SJG also recovers incremental operating and maintenance expenses and earn a return of, and return on, program investments.
	Regulatory actions regarding the EET were as follows:
	•	November 2010 - SJG filed a petition with the BPU requesting a one year extension of the program and a reallocation of investment dollars between the EET programs to fund the more popular programs. In January 2011, SJG’s request to reallocate investment dollars between the programs and a one year extension was approved by the BPU.
	•	June 2011 - SJG filed its annual 2011-2012 petition requesting approval of a $4.7 million increase in EET recovery. This petition was approved in September 2012 with rates effective October1, 2012.
	•	October 2011 - SJG filed a petition requesting a modification of the EET with regards to the Combined Heat and Power (CHP) program. The BPU approved this petition in February 2012.
	•	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 Energy Efficiency Program (“EEP I”) to 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. This petition is still pending.
	•	May 2013 - SJG filed its annual petition requesting an increase of $2.2 million for current EET programs. This petition is still pending.
	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), a Universal Service Fund (USF) program and a Consumer Education Program (CEP).
	Regulatory actions regarding the SBC, with the exception of USF which requires separate regulatory filings, were as follows:
	•	July 2011 - SJG made its annual 2011-2012 SBC filing requesting a $31.2 million increase in SBC recoveries. The BPU approved this filing in July 2013.
	•	September 2011 - The BPU finalized rates for the 2008-2009 and 2009-2010 SBC petitions.
	•	July 2012 - SJG made its annual 2012-2013 SBC filing requesting an $11.8 million increase in SBC recoveries. The BPU approved this filing in July 2013.
	•	September 2012 - The BPU finalized rates for the 2010-2011 SBC petition effective October 1, 2012.
	•	July 2013- SJG made its annual 2013-2014 SBC filing requesting a $6.4 million decrease in SBC revenues. This petition is still 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. Note that 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, 2013 and 2012, SJG reflected the unamortized remediation costs of $29.9 million and $37.9 million, respectively, on the consolidated balance sheets under Regulatory Assets (See Note 11). Since implementing the RAC in 1992, SJG has recovered $92.6 million through rates.
	New Jersey Clean Energy Program (NJCEP) - This mechanism recovers costs associated with SJG's energy efficiency and renewable energy programs.  In August 2008, the BPU approved the statewide funding of the NJCEP of $1.2 billion for the years 2009 through 2012.  Of this amount, SJG was responsible for expensing approximately $41.5 million over the four-year period.  In November 2012, the BPU approved a six-month extension of the program through June 2013. Under this extension, SJG is responsible for $7.5 million of funding. 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 2011 - SJG made its annual USF filing, along with the state's other electric and gas utilities, proposing to decrease annual statewide gas revenues by $9.3 million. This proposal was designed to decrease SJG's annual USF revenue by $0.8 million.
	•	October 2011 - The BPU approved the statewide budget of $57.4 million for all of the State's gas utilities. SJG's portion of the total is approximately $5.4 million, which decreased rates effective November 1, 2011, resulting in a $0.5 million decrease to SJG's annual USF recoveries.
	•	June 2012 - SJG made its annual USF filing, along with the state's other electric and gas utilities, proposing to decrease annual statewide gas revenues by $0.5 million. This proposal was designed to decrease SJG's annual USF revenue by $0.1 million.
	•	September 2012 - The BPU approved the statewide budget of $78.0 million for all of the State's gas utilities. SJG's portion of the total is approximately $8.2 million, which decreased rates effective October 1, 2012, resulting in a $0.1 million decrease to SJG's annual USF recoveries.
	•	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.
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, 2013, 47,074 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 - In October 2005, SJG filed a petition with the BPU to implement a Pipeline Integrity Management Tracker (Tracker). The purpose of this Tracker was to recover incremental costs to be incurred by SJG as a result of new federal regulations, which are aimed at enhancing public safety and reliability. The regulations require that utilities use a comprehensive analysis to assess, evaluate, repair and validate the integrity of certain transmission lines in the event of a leak or failure. As part of SJG's September 2010 base rate increase, SJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2010.  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.  Accordingly, SJG withdrew its petition for the Pipeline Integrity Management Tracker.  As of December 31, 2013 and 2012, deferred pipeline integrity costs totaled $2.8 million and $1.6 million, respectively, and are included in other regulatory assets.
Superstorm Sandy - In June 2013, SJG filed a petition requesting deferral of incremental operating and maintenance expenses incurred due to Superstorm Sandy. These costs totaled $0.7 million and are expected to be recovered in SJG’s next base rate case. This petition is currently pending.
Filings and petitions described above are still pending unless otherwise indicated.

REGULATORY_ASSETS_REGULATORY_L

REGULATORY ASSETS & REGULATORY LIABILITIES	12 Months Ended
	Dec. 31, 2013
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, 2013		December 31, 2012
	Environmental Remediation Costs:
	Expended - Net	$	29,945	$	37,892
	Liability for Future Expenditures	119,492		107,410
	Deferred Asset Retirement Obligation Costs	31,142		30,199
	Deferred Pension and Other Postretirement Benefit Costs	59,284		95,897
	Conservation Incentive Program Receivable	10,526		31,686
	Societal Benefit Costs Receivable	10,408		12,801
	Premium for Early Retirement of Debt	955		1,075
	Deferred Interest Rate Contracts	3,735		7,761
	Energy Efficiency Tracker	10,420		12,306
	Pipeline Supplier Service Charges	7,106		8,771
	Pipeline Integrity Cost	2,902		1,584
	Other Regulatory Assets	10,166		5,274
	Total Regulatory Assets	$	296,081	$	352,656
	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 their 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.  SJG deferred amounts accrued prior to that authorization and amortized them as allowed by the BPU over 15 years through 2012. 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).
	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 program.
	Premium for Early Retirement of Debt - At December 31, 2013, this regulatory asset represents unamortized debt issuance costs related to long-term debt refinancings. Unamortized debt issuance costs are being amortized over the term of the new debt issue pursuant to regulatory approval by the BPU.
	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 2010 base rate increase, SJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2010. 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 3).
	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, 2013		December 31, 2012
	Excess Plant Removal Costs	$	40,029	$	45,593
	Deferred Revenues - Net	19,067		10,924
	Other Regulatory Liabilities	1,853		—
	Total Regulatory Liabilities	$	60,949	$	56,517
	Excess Plant Removal Costs - Represents amounts accrued in excess of actual utility plant removal costs incurred to date.  As part of SJG's September 2010 base rate increase, SJG is required to amortize approximately $1.2 million of this balance to depreciation expense each year.
	Deferred Revenues - 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 SJG's natural gas purchases are also included in the BGSS, subject to BPU approval.  The increase from a $10.9 million regulatory liability at December 31, 2012 to a $19.1 million regulatory liability at December 31, 2013 was due to gas costs recovered from customers exceeding the actual cost of the commodity incurred during 2013.
	Other Regulatory Liabilities - All other regulatory liabilities are subject to being returned to ratepayers in future rate proceedings.

PENSION_AND_OTHER_POSTRETIREME

PENSION AND OTHER POSTRETIREMENT BENEFITS	12 Months Ended
	Dec. 31, 2013
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. The pension plans provide annuity payments to the majority of full-time, regular employees 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
		2013				2012				2011
	Service Cost	$	5,421			$	4,533			$	3,918
	Interest Cost	9,439				9,622				9,524
	Expected Return on Plan Assets	(11,914		)		(10,341		)		(9,367		)
	Amortizations:
	Prior Service Cost	251				251				267
	Actuarial Loss	9,006				7,629				5,440
	Net Periodic Benefit Cost	12,203				11,694				9,782
	ERIP Costs	—				—				102
	Capitalized Benefit Costs	(5,002		)		(4,684		)		(3,661		)
	Total Net Periodic Benefit Expense	$	7,201			$	7,010			$	6,223
		Other Postretirement Benefits
		2013				2012				2011
	Service Cost	$	1,139			$	1,037			$	996
	Interest Cost	2,730				3,001				3,201
	Expected Return on Plan Assets	(2,378		)		(2,105		)		(2,248		)
	Amortizations:
	Prior Service Credits	(283		)		(283		)		(355		)
	Actuarial Loss	1,738				1,725				1,654
	Net Periodic Benefit Cost	2,946				3,375				3,248
	Capitalized Benefit Costs	(1,172		)		(1,340		)		(1,222		)
	Total Net Periodic Benefit Expense	$	1,774			$	2,035			$	2,026
	Capitalized benefit costs reflected in the table above relate to SJG’s construction program.
	The ERIP costs reflected in the table above relate to an early retirement plan offered during 2011 to one of our business segments.
	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 statement 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, 2012	$	61,811			$	26,435			$	31,766		$	4,745
	Amounts Arising during the Period:
	Net Actuarial Loss (Gain)	11,599				2,089				6,811			(446		)
	Amounts Amortized to Net Periodic Costs:
	Net Actuarial Loss	(4,490		)		(1,535		)		(3,103		)	(187		)
	Prior Service (Cost) Credit	(207		)		195				(43		)	83
	Balance at December 31, 2012	68,713				27,184				35,431			4,195
	Amounts Arising during the Period:
	Net Actuarial Gain	(20,554		)		(9,171		)		(4,173		)	(390		)
	Amounts Amortized to Net Periodic Costs:
	Net Actuarial Loss	(5,319		)		(1,555		)		(3,642		)	(177		)
	Prior Service (Cost) Credit	(208		)		194				(42		)	82
	Balance at December 31, 2013	$	42,632			$	16,652			$	27,574		$	3,710
	The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2014 are as follows (in thousands):
		Pension Benefits				Other Postretirement Benefits
	Prior Service Costs	$	158			$	133
	Net Actuarial Loss	$	2,856			$	790
	The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2014 are as follows (in thousands):
		Pension Benefits				Other Postretirement  Benefits
	Prior Service Costs	$	17			$	18
	Net Actuarial Loss	$	2,848			$	182
	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
		2013				2012				2013			2012
	Change in Benefit Obligations:
	Benefit Obligation at Beginning of Year	$	224,389			$	194,990			$	68,779		$	64,451
	Service Cost	5,421				4,533				1,139			1,037
	Interest Cost	9,439				9,622				2,730			3,001
	Actuarial (Gain) Loss	(14,272		)		23,952				(6,361		)	3,861
Retiree Contributions	—				—				388			342
Benefits Paid	(8,582		)		(8,708		)		(4,320		)	(3,913		)
Benefit Obligation at End of Year	$	216,395			$	224,389			$	62,355		$	68,779
Change in Plan Assets:
Fair Value of Plan Assets at Beginning of Year	$	150,160			$	116,718			$	36,032		$	31,896
Actual Return on Plan Assets	22,556				15,935				5,621			4,263
Employer Contributions	13,959				26,215				3,932			3,444
Retiree Contributions	—				—				388			342
Benefits Paid	(8,582		)		(8,708		)		(4,320		)	(3,913		)
Fair Value of Plan Assets at End of Year	$	178,093			$	150,160			$	41,653		$	36,032
Funded Status at End of Year:	$	(38,302	)		$	(74,229	)		$	(20,701	)	$	(32,747	)
Amounts Related to Unconsolidated Affiliate	(7		)		161				365			375
Accrued Net Benefit Cost at End of Year	$	(38,309	)		$	(74,068	)		$	(20,336	)	$	(32,372	)
Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	$	(1,275	)		$	(1,272	)		$	—		$	—
Noncurrent Liabilities	(37,034		)		(72,796		)		(20,336		)	(32,372		)
Net Amount Recognized at End of Year	$	(38,309	)		$	(74,068	)		$	(20,336	)	$	(32,372	)
Amounts Recognized in Regulatory Assets Consist of:
Prior Service Costs	$	634			$	842			$	952		$	758
Net Actuarial Loss	41,998				67,871				15,700			26,426
	$	42,632			$	68,713			$	16,652		$	27,184
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
Prior Service Costs	$	69			$	111			$	150		$	68
Net Actuarial Loss	27,505				35,320				3,560			4,127
	$	27,574			$	35,431			$	3,710		$	4,195
The projected benefit obligation (PBO) and accumulated benefit obligation (ABO) of SJI's qualified employee pension plans were $178.8 million and $163.6 million, respectively, as of December 31, 2013; and $186.4 million and $168.9 million, respectively, as of December 31, 2012.  The ABO of these plans exceeded the value of the plan assets as of December 31, 2012.  The value of these assets can be seen in the table above. The PBO and ABO for SJI's non-funded SERP were $37.6 million and $36.6 million, respectively, as of December 31, 2013; and $38.0 million and $36.3 million, respectively, as of December 31, 2012. 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
	2013			2012			2013			2012
Discount Rate	5.09	%		4.26	%		4.91	%		4.14	%
Rate of Compensation Increase	3.5	%		3.25	%		3.5	%		3.25	%
The weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 were:
	Pension Benefits									Other Postretirement Benefits
	2013			2012			2011			2013		2012			2011
Discount Rate	4.26	%		5.03	%		5.78	%		4.14	%	4.92	%		5.55	%
Expected Long-Term Return on Plan Assets	7.5	%		7.5	%		8	%		6.6	%	6.6	%		7	%
Rate of Compensation Increase	3.25	%		3.25	%		3.25	%		3.25	%	3.25	%		3.25	%
All obligations disclosed herein reflect the use of the RP 2000 mortality tables.
The discount rates used to determine the benefit obligations at December 31, 2013 and 2012, 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:
	2013			2012
Medical Care and Drug Cost Trend Rate Assumed for Next Year	7	%		7	%
Dental Care Cost Trend Rate Assumed for Next Year	4.75	%		4.75	%
Rate to which Cost Trend Rates are Assumed to Decline (the Ultimate Trend Rate)	4.75	%		4.75	%
Year that the Rate Reaches the Ultimate Trend Rate	2023			2019
Assumed health care cost trend rates 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	$	188			$	(149	)
Effect on Postretirement Benefit Obligation	$	2,947			$	(2,483	)
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 2-14 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, 2013.  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, 2013, 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, that 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, 2013 and 2012 by asset category are as follows (in thousands):
Asset Category	Total				Level 1				Level 2			Level 3
As of December 31, 2013
Cash / Cash Equivalents:
Common/Collective Trust Funds (a)	$	416			$	—			$	416		$	—
STIF-Type Instrument (b)	1,177				—				1,177			—
Equity securities:
Common/Collective Trust Funds - U.S. (a)	51,837				—				51,837			—
Common/Collective Trust Funds - International (a)	34,093				—				34,093			—
U.S. Large-Cap (c)	11,661				11,661				—			—
U.S. Mid-Cap (c)	4,135				4,135				—			—
International (c)	3,664				3,664				—			—
Fixed Income:
Common/Collective Trust Funds (a)	45,847				—				45,847			—
Guaranteed Insurance Contract (d)	11,322				—				—			11,322
Hedge Funds (e)	4,154				—				—			4,154
Other types of investments:
Private Equity Fund (f)	3,046				—				—			3,046
Common/Collective Trust Fund - Real Estate (g)	6,741				—				—			6,741
Total	$	178,093			$	19,460			$	133,370		$	25,263
Asset Category	Total				Level 1				Level 2			Level 3
As of December 31, 2012
Cash / Cash Equivalents:
Common/Collective Trust Funds (a)	$	600			$	—			$	600		$	—
STIF-Type Instrument (b)	1,056				—				1,056			—
Equity securities:
Common/Collective Trust Funds - U.S. (a)	42,373				—				42,373			—
Common/Collective Trust Funds - International (a)	29,491				—				29,491			—
U.S. Large-Cap (c)	8,963				8,963				—			—
U.S. Mid-Cap (c)	5,275				5,275				—			—
U.S. Small-Cap (c)	10				10				—			—
International (c)	1,838				1,838				—			—
Fixed Income:
Common/Collective Trust Funds (a)	38,880				—				38,880			—
Guaranteed Insurance Contract (d)	12,449				—				—			12,449
Other types of investments:
Private Equity Fund (f)	3,216				—				—			3,216
Common/Collective Trust Fund - Real Estate (g)	6,009				—				—			6,009
Total	$	150,160			$	16,086			$	112,400		$	21,674
(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 day lag and, therefore, the value reported herein represents the market value as of September 30, 2013 and 2012, respectively.  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, 2012	$	12,274			$	—			$	3,212		$	5,460			$	20,946
Actual return on plan assets:
Relating to assets still held at the reporting date	1,219				—				(190		)	549				1,578
Relating to assets sold during the period	(12		)		—				604			—				592
Purchases, Sales and Settlements	(1,032		)		—				(410		)	—				(1,442		)
Balance at December 31, 2012	12,449				—				3,216			6,009				21,674
Actual return on plan assets:
Relating to assets still held at the reporting date	(179		)		154				76			732				783
Relating to assets sold during the period	17				—				431			—				448
Purchases, Sales and Settlements	(965		)		4,000				(677		)	—				2,358
Balance at December 31, 2013	$	11,322			$	4,154			$	3,046		$	6,741			$	25,263
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 and mutual funds.  The target allocations for post-retirement benefit plan assets are 33-43 percent U.S. equity securities, 20-30 percent international equity securities, and 32-42 percent fixed income 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 fair values of SJI's other postretirement benefit plan assets at December 31, 2013 and 2012 by asset category are as follows (in thousands):
Asset Category	Total				Level 1				Level 2			Level 3
As of December 31, 2013:
Equity Securities:
Common/Collective Trust Funds - U.S. (a)	$	13,098			$	—			$	13,098		$	—
Common/Collective Trust Funds - International (a)	10,586				—				10,586			—
Mutual Fund - U.S. Large-Cap (b)	2,969				2,969				—			—
Fixed Income:
Corporate Bonds (a)	15,000				—				15,000			—
Total	$	41,653			$	2,969			$	38,684		$	—
Asset Category	Total				Level 1				Level 2			Level 3
As of December 31, 2012:
Equity Securities:
Common/Collective Trust Funds - U.S. (a)	$	10,992			$	—			$	10,992		$	—
Common/Collective Trust Funds - International (a)	9,340				—				9,340			—
Mutual Fund - U.S. Large-Cap (b)	2,563				2,563				—			—
Fixed Income:
Corporate Bonds (a)	13,137				—				13,137			—
Total	$	36,032			$	2,563			$	33,469		$	—
(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.
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
2014	$	9,210			$	4,438
2015	$	9,842			$	4,574
2016	$	10,289			$	4,660
2017	$	10,801			$	4,743
2018	$	12,256			$	4,767
2019 - 2023	$	73,827			$	25,293
CONTRIBUTIONS - SJI contributed $12.7 million and $25.0 million to the pension plans during the year ended December 31, 2013 and 2012, respectively. No pension plan contributions are planned for 2014. Payments related to the unfunded SERP plan are expected to approximate $1.3 million in 2014 and have remained consistent over the past few years. 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 $1,000, if 10 or fewer years of service, or $1,500, if more than 10 years of service. The amount expensed and contributed for the matching provision of the Savings Plan approximated $1.7 million, $1.6 million, and $1.5 million for the years ended December 31, 2013, 2012 and 2011, respectively.

LINES_OF_CREDIT

LINES OF CREDIT	12 Months Ended
	Dec. 31, 2013
Line of Credit Facility [Abstract]	'
UNUSED LINES OF CREDIT	'
	LINES OF CREDIT:
	Credit facilities and available liquidity as of December 31, 2013 were as follows (in thousands):
	Company	Total Facility		Usage		Available Liquidity		Expiration Date
	SJG:
	Commercial Paper Program/Revolving Credit Facility	$	200,000	$	65,500	$	134,500	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total SJG	210,000		65,500		144,500
	SJI:
	Revolving Credit Facility	400,000		315,200		84,800		February 2018 (A)
	Total SJI	400,000		315,200		84,800
	Total	$	610,000	$	380,700	$	229,300
	(A) Includes letters of credit outstanding in the amount of $26.8 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 1.04%, 1.10% and 1.12% at December 31, 2013, 2012 and 2011, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2013 and 2012 were $325.6 million and $355.3 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2013 and 2012 were $459.0 million and $462.2 million, respectively.
	SJG renewed its $10.0 million line of credit during the third quarter of 2013.
	In October 2013, SJI entered into an unsecured $50.0 million term loan, which matures in October 2015. This agreement replaces existing facilities that were set to expire in November 2013.
	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, 2013.
	SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million.  The notes  have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes.  SJG uses the commercial paper program in tandem with the 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.

LONGTERM_DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
LONG-TERM DEBT	'
	LONG-TERM DEBT:
	Outstanding Long-Term Debt at December 31 consisted of the following:
			2013			2012
	Long-Term Debt (A):
	South Jersey Gas Company:
	First Mortgage Bonds: (B)
	4.46%	Series due 2013 (C)	$	—		$	10,500
	5.03%	Series due 2013 (C)	—			14,500
	4.52%	Series due 2014	11,000			11,000
	5.12%	Series due 2014	10,000			10,000
	5.39%	Series due 2015	10,000			10,000
	5.44%	Series due 2016	10,000			10,000
	4.60%	Series due 2016	17,000			17,000
	4.66%	Series due 2017	15,000			15,000
	7.97%	Series due 2018	10,000			10,000
	7.12%	Series due 2018	20,000			20,000
	5.59%	Series due 2019	10,000			10,000
	3.00%	Series due 2024 (D)	50,000			50,000
	3.03%	Series due 2024 (D)	35,000			35,000
	3.63%	Series due 2025	10,000			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 (E)	50,000			—
	3.74%	Series due 2032	35,000			35,000
	5.55%	Series due 2033	32,000			32,000
	6.21%	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 (F)		25,000			25,000
	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 (H)
	2.39%	Series A 2012 Notes due 2015	64,000			64,000
	2.71%	Series B 2012 Notes due 2017	16,000			16,000
	3.46%	Series C 2012 Notes due 2022	35,000			35,000
	South Jersey Industries Term Loan at variable rates due 2015 (I)		50,000			—
	Total Long-Term Debt Outstanding		701,400			626,400
	Less Current Maturities		(21,000		)	(25,000		)
	Total Long-Term Debt		$	680,400		$	601,400
	(A)	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000.
	(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 July 2013, SJG called its $10.5 million, 4.46% MTN due July 2013 and $14.5 million, 5.027% MTN due September 2013.
	(D)	In September 2012, SJG issued $50.0 million of 3.00% aggregate principal amount of MTN's due September 2024. In November 2012, SJG issued $35.0 million of 3.03% aggregate principal amount of MTN's due November 2024.
	(E)	In November 2013, SJG issued $50.0 million of 4.01% aggregate principal amount of its MTN's due November 2030.
	(F)	These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2013 was 0.07%. Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August, 2015. These bonds contain no financial covenants.
	(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, 2013 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.08%, 0.18% and 0.08% respectively. The interest rate on all but $27.1 million of the bonds has been effectively fixed via interest rate swaps at 4.41% 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 August, 2015.
	(H)	In June 2012, the Company issued $115.0 million aggregate principal amount of long-term debt, consisting of the following: (a) $64.0 million aggregate principal amount of 2.39% Senior Notes due June 2015; (b) $16.0 million aggregate principal amount of 2.71% Senior Notes due June 2017; and (c) $35.0 million aggregate principal amount of 3.46% Senior Notes due June 2022.
	(I)	In October 2013, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2015. This agreement replaces existing facilities that were set to expire in November 2013. The variable rate at December 31, 2013 was 1.22%. These notes have been reclassified from Notes Payable-Banks to Long-Term Debt on the consolidated balances sheets, but are not included in the consolidated statement of cash flows as the reclassification is considered a non-cash financing activity.
	In December 2011, SJG received approval from the BPU to issue up to $200.0 million in long-term debt under its MTN program by September 2014. At December 31, 2013, $30.0 million was available under this program.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2013
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 $0.4 million per month. SJG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services averages approximately $4.0 million per month and is recovered on a current basis through the BGSS.  SJRG has also committed to purchase a minimum of 545,500 dts/d and up to 810,000 dts/d of natural gas, from various suppliers, for terms ranging from three to ten years at index based prices.
	PENDING LITIGATION - The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain 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 $3.0 million and $3.1 million related to all claims in the aggregate as of December 31, 2013 and 2012, 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, 2013. 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 employees represented by the IBEW operate under a collective bargaining agreement that runs through February 28, 2017. SJESP employees represented by the IBEW operated under a collective bargaining agreement that was set to expire February 28, 2014, however a new collective bargaining agreement was agreed to which commences on March 1, 2014 and runs through February 28, 2017. The remaining unionized employees represented by the IAM operate under a collective bargaining agreement that expires in August 2014.
	GUARANTEES - As of December 31, 2013, 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, 2013, these guarantees support future firm commitments of SJI's consolidated subsidiaries and $114.4 million of the Accounts Payable already recorded on SJI's consolidated balance sheet.
	The Company has recorded a liability of $0.7 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the consolidated balance sheets as of December 31, 2013 for the fair value of the following guarantees:
	In April 2007, SJI guaranteed certain obligations of LVE Energy Partners, LLC (LVE) an unconsolidated joint venture in which Marina had a 50% equity interest.  LVE entered into a 25-year contract with a resort developer to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.  LVE began construction of the facility in 2007 and expected to provide full energy service in 2010 when the resort was originally scheduled to be completed.  LVE suspended construction of the district energy system and central energy center in January 2009 after the resort developer’s announcement that it was delaying the completion of construction of the resort.
	In March 2013, the resort developer purchased substantially all of the assets of LVE. As a result, the guarantees provided by SJI of certain performance obligations of LVE under the operating agreements between LVE and the resort developer were canceled.
	During the twelve months ended December 31, 2013, the Company received $57.9 million of repayments of advances to LVE and a $7.9 million note receivable from a third party. As of December 31, 2013, LVE was dissolved and the Company incurred a $0.8 million charge to write-off the remaining interest. During 2013, SJI provided support to LVE of approximately $3.2 million to cover interest and other project related costs.
	SJI has guaranteed certain obligations of WC Landfill Energy, LLC (WCLE) and BC Landfill Energy, LLC (BCLE), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. WCLE and BCLE have entered into agreements through 2018 and 2027, respectively, with the respective county governments to lease and operate facilities that will produce electricity from landfill methane gas.  Although unlikely, the maximum amount that SJI could be obligated for, in the event that WCLE and BCLE do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due, is approximately $4.2 million each year.  SJI and its partner in these joint ventures have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.  SJI holds variable interests in WCLE and BCLE but is not the primary beneficiary.
	In December 2013, SJI entered into an agreement to guarantee certain obligations of WCLE, SC Landfill Energy, LLC, SX Landfill Energy, LLC, FC Landfill Energy, LLC, and AC Landfill Energy, LLC (collectively, the "Landfills"), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. The landfills have entered into long-term debt agreements which run through 2020. Although unlikely, SJI could be liable through the guarantee for 50% of the outstanding debt along with any interest related to the debt in the event the landfills do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due. As of December 31, 2013, 50% of the currently outstanding debt is $9.7 million. As a result, the Company has recorded a liability of $0.5 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the consolidated balance sheets as of December 31, 2013.
	In February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 20 year contract with a developer 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, ACR is providing full energy services to the complex. Marina and its joint venture partner have agreed to provide a $5.0 million letter of credit to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI to or on behalf of ACR.
	In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 30 year contract with a public university to build, own and operate a combined heating, cooling and power system for its main campus in New Jersey. The system commenced commercial operations in September 2013. SJI has guaranteed certain obligations of UMM under the operating and lease agreements between UMM and the university, for the terms of the agreements, commencing with the first year of operations. SJI has guaranteed up to $2.2 million for the first year. This amount is adjusted each year based upon the Consumer Price Index. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.
	As of December 31, 2013, SJI had issued $6.8 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, 2013, SJI provided $26.8 million of standby letters of credit through SJI’s revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system 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 were 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 $342.7 million, of which $219.3 million was spent as of December 31, 2013.
	The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands):
		2013			2012
	Beginning of Year	$	112,098		$	94,160
	Accruals	22,821			30,349
	Expenditures	(11,490		)	(12,411		)
	End of Year	$	123,429		$	112,098
	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 $119.5 million to $223.5 million. Six of SJG's sites comprise the majority of these estimates, the sum of the six sites range from a low of $100.4 million to a high of $192.8 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 completion of the remedial investigation of impacted soil and groundwater, selection of the appropriate remedial action, receiving confirmation of regulatory compliance of the selected remedy, and implementation of the approved remedy.
	Site 2 - Remediation of the site is underway in accordance with the approved Remedial Action Work plan. Steps remaining to remediate the site include continued excavation of impacted soil and post remediation groundwater monitoring.
	Site 3 - 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 receiving confirmation of regulatory compliance of the selected remedy and implementation of the approved remedy.
	Site 4 - Remedial investigation activities are ongoing at this site including pilot studies of potential remedial alternatives and continued soil and groundwater investigation.  Remaining steps to remediate include completion of the remedial investigation of impacted soil and groundwater, selection of the appropriate remedial action, receiving confirmation of regulatory compliance of the selected remedy, and implementation of the approved remedy.
	Sites 5 and 6 - Remedial investigation activities are ongoing at these sites.  Remaining steps to remediate include completion of the remedial investigation of impacted soil and groundwater, selection of the appropriate remedial action, receiving confirmation of regulatory compliance of the selected remedy, and implementation of the approved remedy.
	With Morie's sale in 1996, EMI assumed responsibility for environmental liabilities currently estimated between $3.0 million and $5.5 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 $0.9 million to $1.8 million. The lower end of this range has been recorded under Current Liabilities and Deferred Credits and Other Noncurrent Liabilities as of December 31, 2013.

DERIVATIVE_INSTRUMENTS

DERIVATIVE INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
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, 2013, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 17.9 MMdts of expected future purchases of natural gas, 19.1 MMdts of expected future sales of natural gas, 1.3 MMmwh of expected future purchases of electricity and 1.3 MMmwh of expected future sales of electricity.  In addition to these derivative contracts, the Company had basis and index related purchase and sales contracts totaling 21.8 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.
	SJE transacts 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.
	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.
	SJI presents revenues and expenses related to its energy trading activities on a net basis in Operating Revenues - Nonutility in the consolidated statements of income consistent with GAAP. This net presentation has no effect on operating income or net income.
	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. Beginning in July 2012, hedge accounting was discontinued for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously included in Accumulated Other Comprehensive Loss on the consolidated balance sheets, will be reclassified into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026.
	As of December 31, 2013, SJI's active interest rate swaps were as follows:
	Notional Amount				Fixed Interest Rate		Start Date		Maturity		Type of Debt		Obligor
	$	3,900,000			4.80%		12/1/04		12/1/14		Taxable		Marina
	$	8,000,000			4.78%		11/12/04		11/12/14		Taxable		Marina
	$	14,500,000			3.91%		3/17/06		1/15/26		Tax-exempt		Marina
	$	500,000			3.91%		3/17/06		1/15/26		Tax-exempt		Marina
	$	330,000			3.91%		3/17/06		1/15/26		Tax-exempt		Marina
	$	7,100,000			4.90%		2/1/06		2/1/16		Taxable		Marina
	$	12,500,000			3.43%		12/1/06		2/1/36		Tax-exempt		SJG
	$	12,500,000			3.43%		12/1/06		2/1/36		Tax-exempt		SJG
	The unrealized gains and losses on interest rate derivatives that are not designated as cash flow hedges are included in Interest Charges. However, for selected interest rate derivatives at SJG, management believes that, subject to BPU approval, the market value upon termination can be recovered in rates and therefore these unrealized losses have been included in Other Regulatory Assets in the consolidated balance sheets.
	The fair values of all derivative instruments, as reflected in the consolidated balance sheets as of December 31, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP		2013								2012
			Assets				Liabilities				Assets				Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current		$	56,327			$	77,993			$	24,242			$	23,828
	Derivatives – Energy Related – Non-Current		26,451				22,131				12,297				5,403
	Interest rate contracts:
	Derivatives - Other		—				6,676				—				13,462
	Total derivatives not designated as hedging instruments under GAAP		82,778				106,800				36,539				42,693
	Total Derivatives		$	82,778			$	106,800			$	36,539			$	42,693
	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, 2013 and 2012, information related to these offsetting arrangements were as follows (in thousands):
	As of December 31, 2013
	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		82,778			—			$	82,778			(28,082	)	(A)	(498	)	$	54,198
	Derivatives - Energy Related Liabilities		(100,124	)		—			$	(100,124	)		28,082		(B)	29,639		$	(42,403	)
	Derivatives - Other		(6,676	)		—			$	(6,676	)		—			—		$	(6,676	)
	As of December 31, 2012
	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		36,539			—			$	36,539			(12,975	)	(A)	—		$	23,564
	Derivatives - Energy Related Liabilities		(29,231	)		—			$	(29,231	)		12,975		(B)	6,347		$	(9,909	)
	Derivatives - Other		(13,462	)		—			$	(13,462	)		—			—		$	(13,462	)
	(A) The balances at December 31, 2013 and 2012 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at December 31, 2013 and 2012 were related to derivative assets which can be net settled against derivative liabilities.
	The effect of derivative instruments on the consolidated statements of income and comprehensive income for the year ended December 31 is as follows (in thousands):
	Derivatives in Cash Flow Hedging Relationships		2013				2012				2011
	Interest Rate Contracts:
	Losses recognized in AOCL on effective portion		$	—			$	(752	)		$	(2,773	)
	Losses reclassified from AOCL into income (a)		$	(448	)		$	(594	)		$	(1,435	)
	Losses recognized in income on ineffective portion (a)		—				—				—
	(a) Included in Interest Charges
	Derivatives Not Designated as Hedging Instruments under GAAP		2013				2012				2011
	(Losses) gains on energy related commodity contracts (a)		$	(25,823	)		$	(193	)		$	5,377
	Gains (losses) on interest rate contracts (b)		2,760				660				(149		)
	Total		$	(23,063	)		$	467			$	5,228
	(a)  Included in Operating Revenues - Non Utility
	(b)  Included in Interest Charges
	Net realized losses associated with SJG’s energy-related financial commodity contracts of $0.4 million, $15.4 million and $12.9 million for the years ended 2013, 2012 and 2011, 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 to earnings.
	Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on December 31, 2013, is $38.7 million.   If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2013, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $29.8 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, 2013
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, 2013	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,716			$	8,716			$	—	$	—
	Derivatives – Energy Related Assets (B)	82,778				4,385				27,182		51,211
		$	91,494			$	13,101			$	27,182	$	51,211
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	100,124			$	4,236			$	52,772	$	43,116
	Derivatives – Other (C)	6,676				—				6,676		—
		$	106,800			$	4,236			$	59,448	$	43,116
	As of December 31, 2012	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	7,538			$	787			$	6,751	$	—
	Derivatives – Energy Related Assets (B)	36,539				9,404				16,205		10,930
		$	44,077			$	10,191			$	22,956	$	10,930
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	29,231			$	5,399			$	15,664	$	8,168
	Derivatives – Other (C)	13,462				—				13,462		—
		$	42,693			$	5,399			$	29,126	$	8,168
	(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, 2013						Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets			Liabilities
	Forward Contract - Natural Gas	$	41,444		$	36,043		Discounted Cash Flow	Forward price (per dt)	$(1.75) - $6.05 [$(0.79)]
	Forward Contract - Electric	$	9,767		$	7,073		Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [54.55%]
									Fixed electric load profile (off-peak)	0.00% - 91.94% [45.45%]
	Type	Fair Value at December 31, 2012				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets		Liabilities
	Forward Contract - Natural Gas	4,340		4,986		Discounted Cash Flow	Forward price (per dt)	$(0.35) - $2.92 [$(0.12)]
	Forward Contract - Electric	6,590		3,182		Discounted Cash Flow	Fixed electric load profile (on-peak)	21.62% - 100.00% [53.64%]
							Fixed electric load profile (off-peak)	0.00% - 78.38% [46.36%]
	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
			Year Ended December 31, 2013
	Balance at January 1, 2013		$	2,762
	Other changes in fair value from continuing and new contracts, net		1,573
	Transfers in/(out) of Level 3 (A)		2,748
	Settlements		1,012
	Balance at December 31, 2013		$	8,095
	(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, 2013, $2.7 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data.
			Year Ended December 31, 2012
	Balance at January 1, 2012		$	(5,958	)
	Other changes in fair value from continuing and new contracts, net		2,902
	Settlements		5,818
	Balance at December 31, 2012		$	2,762
	Total gains for 2013 included in earnings that are attributable to the change in unrealized gains relating to those assets and liabilities still held as of December 31, 2013, is $5.3 million.  These gains are included in Operating Revenues-Nonutility on the consolidated statements of income.

ACCUMULATED_OTHER_COMPREHENSIV

ACCUMULATED OTHER COMPREHENSIVE LOSS	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
ACCUMULATED OTHER COMPREHENSIVE LOSS	'
	ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL):
	The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2013 (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, 2013 (a)	$	(23,437	)	$	(2,962	)	$	294		$	(5,000	)	$	(31,105	)
	Other comprehensive income before reclassifications	2,699						592						3,291
	Amounts reclassified from AOCL (b)	2,235			265			(489		)	5,043			7,054
	Net current period other comprehensive income	4,934			265			103			5,043			10,345
	Balance at December 31, 2013 (a)	$	(18,503	)	$	(2,697	)	$	397		$	43		$	(20,760	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
	The following table provides details about reclassifications out of AOCL for the year ended December 31, 2013 (in thousands):
		Amounts Reclassified from AOCL			Affected Line Item in the Condensed Consolidated Statements of Income
		For the Year Ended December 31, 2013
	Actuarial Loss on Postretirement Benefits	$	3,779		Operating Expenses: Operations
	Income Taxes	(1,544		)	Income Taxes (a)
		$	2,235
	Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	448		Interest Charges
	Income Taxes	(183		)	Income Taxes (a)
		$	265
	Unrealized Loss on Available-for-Sale Securities	$	(828	)	Other Income
	Income Taxes	339			Income Taxes (a)
		$	(489	)
	Income of Affiliated Companies	$	8,515		Equity in Loss of Affiliated Companies
	Income Taxes	(3,472		)	Income Taxes (a)
		$	5,043
	Losses from reclassifications for the period net of tax	$	7,054

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
SUBSEQUENT EVENTS	'
	SUBSEQUENT EVENTS:
	In January 2014, SJG issued $30.0 million aggregate principal amount of SJG's 4.23% MTN's due January 2030.
	In October 2013, SJG filed a petition with the New Jersey Board of Public Utilities to issue up to $200.0 million of long term debt securities in various forms including Medium Term Notes and unsecured debt, with maturities of more than twelve months, over the next three years. This petition was approved in January 2014.

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2013
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)
			2013 Quarter Ended												2012 Quarter Ended
			31-Mar			30-Jun			Sept. 30			Dec. 31			31-Mar			30-Jun			Sept. 30			Dec. 31
	Operating Revenues		$	255,631		$	122,592		$	128,808		$	224,390		$	274,832		$	121,913		$	111,977		$	197,558
	Expenses:
	Cost of Sales - (Excluding depreciation)		152,301			87,827			89,160			139,703			156,868			69,519			70,549			120,866
	Operations and Maintenance Including Fixed Charges		52,226			47,114			47,789			54,674			46,071			45,467			45,970			50,072
	Income Taxes		7,772			(11,632		)	(5,533		)	(9,621		)	15,884			(1,072		)	(2,576		)	(757		)
	Energy and Other Taxes		3,833			1,664			1,458			2,861			3,878			1,865			1,494			2,749
	Total Expenses		216,132			124,973			132,874			187,617			222,701			115,779			115,437			172,930
	Other Income and Expense		3,838			3,297			2,845			2,584			2,080			4,698			5,624			941
	Income (Loss) from Continuing Operations		43,337			916			(1,221		)	39,357			54,211			10,832			2,164			25,569
	Loss from Discontinued Operations  -  (Net of tax benefit)		(471		)	(28		)	(200		)	(97		)	(136		)	(498		)	(151		)	(383		)
	Net Income (Loss)		$	42,866		$	888		$	(1,421	)	$	39,260		$	54,075		$	10,334		$	2,013		$	25,186
	Basic Earnings Per Common Share:
	Continuing Operations		$	1.37		$	0.03		$	(0.04	)	$	1.22		$	1.79		$	0.36		$	0.07		$	0.81
	Discontinued Operations		(0.02		)	—			—			—			—			(0.02		)	(0.01		)	(0.01		)
	Basic Earnings Per Common Share		$	1.35		$	0.03		$	(0.04	)	$	1.22		$	1.79		$	0.34		$	0.07		$	0.8
	Average Shares of Common Stock Outstanding - Basic		31,757			31,949			31,984			32,259			30,249			30,393			30,861			31,465
	Diluted Earnings Per Common Share:
	Continuing Operations		$	1.36		$	0.03		$	(0.04	)	$	1.22		$	1.79		$	0.36		$	0.07		$	0.81
	Discontinued Operations		(0.01		)	—			—			—			(0.01		)	(0.02		)	(0.01		)	(0.01		)
	Diluted Earnings Per Common Share		$	1.35		$	0.03		$	(0.04	)	$	1.22		$	1.78		$	0.34		$	0.07		$	0.8
	Average Shares of Common Stock Outstanding - Diluted		31,811			32,012			31,984			32,306			30,323			30,472			30,945			31,547
	The sum of the quarters for 2013 and 2012 do not equal the year's total due to rounding.
	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, 2013
Condensed Financial Information of Parent Company Only Disclosure [Abstract]	'
Schedule I	'
	SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
	CONDENSED STATEMENTS OF INCOME
	(In Thousands)
			2013			2012			2011
	Management Service Fee Revenues		$	16,269		$	15,449		$	13,117
	Operating Expenses:
	Operations		14,979			13,869			12,390
	Depreciation		260			183			160
	Energy and Other Taxes		465			419			611
	Total Operating Expenses		15,704			14,471			13,161
	Operating Income (Loss)		565			978			(44		)
	Other Income:
	Equity in Earnings of Subsidiaries		82,389			92,776			89,859
	Other		5,459			3,270			2,688
	Total Other Income		87,848			96,046			92,547
	Interest Charges		6,004			4,219			2,648
	Income Taxes		20			29			(4		)
	Income from Continuing Operations		82,389			92,776			89,859
	Equity in Undistributed Earnings of Discontinued Subsidiaries		(796		)	(1,168		)	(568		)
	Net Income		$	81,593		$	91,608		$	89,291
	SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
	CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
	(In Thousands)
			2013			2012			2011
	Net Income		$	81,593		$	91,608		$	89,291
	Other Comprehensive Loss - Net of Tax*
	Postretirement Liability Adjustment		4,934			(1,842		)	(5,667		)
	Unrealized Gain (Loss) on Available-for-Sale Securities		103			500			(360		)
	Unrealized Gain (Loss) on Derivatives		5,308			(1,325		)	(599		)
	Total Other Comprehensive Income (Loss) - Net of Tax*		10,345			(2,667		)	(6,626		)
	Comprehensive Income		$	91,938		$	88,941		$	82,665
	*  Determined using a combined statutory tax rate of 41%
	SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
	CONDENSED STATEMENTS OF RETAINED EARNINGS
	(In Thousands)
			2013			2012			2011
	Retained Earnings - Beginning		$	382,127		$	341,677		$	297,473
	Net Income		81,593			91,608			89,291
			463,720			433,285			386,764
	Dividends Declared - Common Stock		(57,679		)	(51,158		)	(45,087		)
	Retained Earnings - Ending		$	406,041		$	382,127		$	341,677
	SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
	CONDENSED STATEMENTS OF CASH FLOWS
	FOR THE TWELVE MONTHS ENDED DECEMBER 31,
	(In Thousands)
			2013			2012			2011
	CASH PROVIDED BY OPERATING ACTIVITIES		$	1,316		$	1,840		$	14,179
	CASH FLOWS FROM INVESTING ACTIVITIES:
	Net (Advances to) Repayment from Associated Companies		(68,900		)	(174,593		)	22,957
	Capital Expenditures		(360		)	(454		)	(299		)
	Proceeds from Sale of Property, Plant & Equipment		6			29			—
	Purchase of Company Owned Life Insurance		(5,149		)	(4,547		)	(4,628		)
	Investment in Affiliate		(25,000		)	—			—
	Net Cash (Used In) Provided by Investing Activities		(99,403		)	(179,565		)	18,030
	CASH FLOWS FROM FINANCING ACTIVITIES:
	Proceeds from Issuance of Long Term Debt		—			115,000			—
	Payments for Issuance of Long Term Debt		—			(665		)	—
	Net Borrowing from Lines of Credits		101,600			42,000			3,013
	Dividends on Common Stock		(57,679		)	(50,942		)	(44,975		)
	Proceeds from Sale of Common Stock		54,028			70,241			13,436
	Net Cash Provided by (Used In) Financing Activities		97,949			175,634			(28,526		)
	NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS		(138		)	(2,091		)	3,683
	CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR		1,969			4,060			377
CASH AND CASH EQUIVALENTS AT END OF YEAR		$	1,831		$	1,969		$	4,060
SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED BALANCE SHEETS (In Thousands)
		2013			2012
Assets
Property Plant and Equipment:
Nonutility Property, Plant and Equipment, at cost		$	1,506		$	1,165
Accumulated Depreciation		(752		)	(510		)
Property, Plant and Equipment - Net		754			655
Investments:
Investments in Subsidiaries		887,671			770,127
Available-for-Sale Securities		21			18
Total Investments		887,692			770,145
Current Assets:
Cash and Cash Equivalents		1,831			1,969
Receivable from Associated Companies		358,620			289,635
Accounts Receivable		46			16
Other		1,510			3,401
Total Current Assets		362,007			295,021
Other Noncurrent Assets		35,882			29,624
Total Assets		$	1,286,335		$	1,095,445
Capitalization and Liabilities
Equity:
Common Stock SJI
Par Value $1.25 a share
Authorized - 60,000,000 shares
Outstanding - 32,715,042 (2013) shares and 31,653,262 (2012)		40,894			$	39,567
Premium on Common Stock		401,011			345,807
Treasury Stock (at par)		(186		)	(182		)
Accumulated Other Comprehensive Loss		(20,760		)	(31,105		)
Retained Earnings		406,041			382,127
Total Equity		827,000			736,214
Long-Term Debt		165,000			115,000
Current Liabilities:
Notes Payable - Banks		288,400			236,800
Payable to Associated Companies		257			172
Accounts Payable		322			510
Other Current Liabilities		2,063			1,923
Total Current Liabilities		291,042			239,405
Other Noncurrent Liabilities		3,293			4,826
Total Capitalization and Liabilities		$	1,286,335		$	1,095,445
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 $12.7 million in 2011. No dividends were received from subsidiaries in 2013 and 2012.

Schedule_II_Valuation_and_Qual

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2013
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
	31-Dec-13	$	5,924	$	4,245	$	(41	)	$	4,274	$	5,854
	Provision for Uncollectible
	Accounts for the Year Ended
	31-Dec-12	$	5,337	$	4,932	$	110		$	4,455	$	5,924
	Provision for Uncollectible
	Accounts for the Year Ended
	31-Dec-11	$	8,071	$	2,272	$	562		$	5,568	$	5,337
	(a) Recoveries of accounts previously written off and minor adjustments.
	(b) Uncollectible accounts written off.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2013
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 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.
	▪	Marina Energy, LLC (Marina) develops and operates on-site energy-related projects.
	▪	South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets on a wholesale basis in the mid-Atlantic, Appalachian and southern states.
	▪	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.
	▪	South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.
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 and operating results at the dates and for the periods presented.
	Certain reclassifications have been made to the prior periods regulatory assets disclosure to conform to the current period presentation. The deferred pipeline integrity cost previously included in "Other Regulatory Assets" was reclassified to the line item "Pipeline Integrity Cost" in the regulatory asset table disclosed in Note 11.
	Certain reclassifications have been made to the prior period segment disclosures to conform to the current period presentation. In all periods presented, net receivables between the Discontinued Operations segment and the Corporate and Services segment have been reclassified in the Identifiable Assets Segment disclosure in Note 8.
EQUITY INVESTMENTS	'
	EQUITY INVESTMENTS - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. SJI, through wholly owned subsidiaries, holds significant variable interests in several companies but is not the primary beneficiary.  Consequently, these investments are accounted for under the equity method. In the event that losses and/or distributions from these equity method investments exceed the carrying value, and the Company is obligated to provide additional financial support, the excess will be recorded as either a current or non-current liability on the consolidated balance sheets. We include the operations of these affiliated companies on a pre-tax basis in the statements of consolidated income under Equity in Earnings (Loss) of Affiliated Companies (See Note 3).  An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary.  No impairment losses were recorded on Investments during 2013, 2012 or 2011.
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 FASB ASC Topic 980 -”Regulated Operations.”  In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 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. 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 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). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). 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 2.3% in 2013, 2.4% in 2012, and 2.3% in 2011. 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 its last base rate proceeding (see Note 10). Marina capitalizes interest on construction 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 consolidated statements of 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. In July 2012, hedge accounting was 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. As of December 31, 2013 and 2012, SJI held 148,890 and 145,414 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	'
	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 the non-regulated entities 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.
NEW ACCOUNTING PRONOUNCEMENTS	'
	NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2013, 2012 or 2011 had, or is expected to have, a material impact on the consolidated financial statements.
	In January 2012, the FASB issued ASU 2011-11, Enhanced Disclosure Requirements Concerning Offsetting of Financial Assets and Financial Liabilities. This ASU amends ASC 210-20 to add disclosure requirements in respect of the offsetting of financial assets and financial liabilities. In February 2013, the FASB issued ASU 2013-01 Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which amends and clarifies the scope of the balance sheet offsetting disclosures required through ASU 2011-11. The new guidance is effective for fiscal years beginning on or after January 1, 2013. The adoption of this guidance modified the disclosures around derivative instruments, but did not have an impact on the Company's financial statement results.
	In February 2013, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.
	In July 2013, the FASB issued ASU 2013-11, Balance Sheet Presentation of an Unrecognized Income Tax Benefit for a Net Operating Loss or Tax Credit Carryforward. This ASU provides that a liability related to an unrecognized tax benefit should be offset against a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. Management does not anticipate that the adoption of this guidance will have an impact on the Company's financial statement results.
FAIR VALUE	'
	(A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly.  The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy.  The remaining securities consist of funds that are not publicly traded.  These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy.
	(B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable.
	Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial 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_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Asset retirement obligation activity	'
	ARO activity was as follows (in thousands):
		2013		2012
	AROs as of January 1,	39,385		29,430
	Accretion	1,530		1,872
	Additions	743		1,438
	Settlements	(1,630	)	(1,603	)
	Revisions in Estimated Cash Flows (A)	1,659		8,248
	ARO's as of December 31,	41,687		39,385
	(A) The revision in estimated cash flows in 2013 reflects an increase in the inflation rate used to determine the ARO settlement amount. In 2012, the revision in estimated cash flows reflected increases in the contractual cost as well as changes in the discount rates used to determine the ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.

STOCKBASED_COMPENSATION_PLAN_T

STOCK-BASED COMPENSATION PLAN (Tables)	12 Months Ended
	Dec. 31, 2013
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, 2013 and the assumptions used to estimate the fair value of the awards:
		Grant Date		Shares Outstanding			Fair Value Per Share				Expected Volatility		Risk-Free Interest Rate
	Officers & Key Employees -	Jan. 2012 - TSR		19,810			$	51.23			22.5	%	0.43	%
		Jan. 2012 - EPS		19,810			$	56.93			N/A		N/A
		Jan. 2013 - TSR		27,286			$	44.38			21.1	%	0.4	%
		Jan. 2013 - EPS		27,286			$	51.18			N/A		N/A
	Directors -	Jan. 2011		7,332			$	52.94			—		—
		Jan. 2013		12,285			$	51.74			—		—
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):
		2013				2012				2011
	Officers & Key Employees	$	2,236			$	2,096			$	1,852
	Directors	765				896				658
	Total Cost	3,001				2,992				2,510
	Capitalized	(237		)		(231		)		(218		)
	Net Expense	$	2,764			$	2,761			$	2,292
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 2013, excluding accrued dividend equivalents:
		Officers & Other Key Employees			Directors			Weighted
								Average
								Fair Value
	Nonvested Shares Outstanding, January 1, 2013	81,005			27,688			$	51.29
	Granted	56,464			12,285			$	48.49
	Vested*	(39,720	)		(20,356	)		$	49.2
	Cancelled/Forfeited	(3,557	)		—			$	50.28
	Nonvested Shares Outstanding, December 31, 2013	94,192			19,617			$	50.73
	*Performance targets during the three-year vesting period were not attained for the January 2011 grant. As a result, no shares will be awarded in 2014.

DISCONTINUED_OPERATIONS_AND_AF1

DISCONTINUED OPERATIONS AND AFFILIATIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Summarized operating results of the discontinued operations	'
	Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts):
		2013			2012			2011
	Loss before Income Taxes:
	Sand Mining	$	(406	)	$	(1,396	)	$	(169	)
	Fuel Oil	(816		)	(401		)	(701		)
	Income Tax Benefits	426			629			302
	Loss from Discontinued Operations — Net	$	(796	)	$	(1,168	)	$	(568	)
	Earnings Per Common Share from
	Discontinued Operations — Net:
	Basic	$	(0.03	)	$	(0.04	)	$	(0.02	)
	Diluted	$	(0.02	)	$	(0.04	)	$	(0.02	)
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):
		2013			2012
	Current assets		$	57,725		$	57,711
	Noncurrent assets		$	494,933		$	759,996
	Current liabilities		$	60,355		$	211,628
	Noncurrent liabilities		$	341,548		$	460,560
		2013			2012			2011
	Revenues		$	178,026		$	148,009		$	95,647
	Cost of sales		$	91,228		$	71,141		$	64,181
	Income from continuing operations		$	6,229		$	5,795		$	1,522
	Net Income		$	6,229		$	5,795		$	1,522

INCOME_TAXES_Tables

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2013
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):
		2013			2012			2011
	Tax at Statutory Rate	$	22,181		$	36,490		$	39,326
	Increase (Decrease) Resulting from:
	State Income Taxes	971			5,857			6,763
	ESOP	(1,176		)	(1,141		)	(1,063		)
	Amortization of Investment Tax Credits - Utility	(258		)	(287		)	(302		)
	Amortization of Flowthrough Depreciation	—			—			526
	AFUDC	(916		)	(1,048		)	(729		)
	Investment and Other Tax Credits	(38,179		)	(26,574		)	(21,927		)
	Other - Net	(1,637		)	(1,818		)	(92		)
	Income Taxes:
	Continuing Operations	(19,014		)	11,479			22,502
	Discontinued Operations	(426		)	(629		)	(302		)
	Net Income Taxes	$	(19,440	)	$	10,850		$	22,200
	The provision for Income Taxes is comprised of the following (in thousands):
		2013			2012			2011
	Current:
	Federal	$	(273	)	$	(8,761	)	$	(844	)
	State	3,066			221			345
	Total Current	2,793			(8,540		)	(499		)
	Deferred:
	Federal	(19,978		)	11,515			13,244
	State	(1,571		)	8,791			10,059
	Total Deferred	(21,549		)	20,306			23,303
	Investment Tax Credit - Utility	(258		)	(287		)	(302		)
	Income Taxes:
	Continuing Operations	(19,014		)	11,479			22,502
	Discontinued Operations	(426		)	(629		)	(302		)
	Net Income Taxes	$	(19,440	)	$	10,850		$	22,200
Schedule of deferred tax assets and liabilities	'
	The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax liabilities (assets) at December 31 (in thousands):
		2013			2012
	Current:
	Net Operating Loss Carryforward	$	(26,800	)	$	(2,586	)
	Derivatives / Unrealized Gain	(8,608		)	257
	Conservation Incentive Program	4,631			13,942
	Budget Billing - Customer Accounts	1,152			1,033
	Provision for Uncollectibles	(1,994		)	(1,883		)
	Other	1,010			49
	Current Deferred Tax (Asset) Liability  - Net	$	(30,609	)	$	10,812
	Noncurrent:
	Book versus Tax Basis of Property	$	476,039		$	395,322
	Deferred Gas Costs - Net	1,330			3,325
	Environmental	13,017			16,006
	Deferred Regulatory Costs	13,665			15,374
	Deferred State Tax	(17,949		)	(17,924		)
	Investment Tax Credit Basis Gross-Up	(185		)	(318		)
	Deferred Pension & Other Post Retirement Benefits	24,218			39,174
	Pension & Other Post Retirement Benefits	(17,777		)	(33,739		)
	Deferred Revenues	(9,593		)	(9,367		)
	Derivatives / Unrealized  Gain	2,149			(82		)
	Net Operating Loss Carryforward	(90,818		)	(79,217		)
	Investment and Other Tax Credits	(117,726		)	(71,547		)
	Equity In Loss Of Affiliated Companies	37,764			30,707
	Other	5,234			1,775
	Noncurrent Deferred Tax Liability - Net	$	319,368		$	289,489
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):
		2013			2012			2011
	Balance at January 1,	$	503		$	736		$	793
	Increase as a result of tax positions taken in prior years	44			108			119
	Decrease due to a lapse in the statute of limitations	—			(341		)	(90		)
	Settlements	—			—			(86		)
	Balance at December 31,	$	547		$	503		$	736

COMMON_STOCK_Tables

COMMON STOCK (Tables)	12 Months Ended
	Dec. 31, 2013
Common Stock [Abstract]	'
Common stock shares issued and outstanding	'
	The following shares were issued and outstanding at December 31:
		2013	2012	2011
	Beginning of Year	31,653,262	30,212,453	29,872,825
	New Issues During Year:
	Dividend Reinvestment Plan	983,417	1,397,583	259,359
	Stock-Based Compensation Plan	78,363	43,226	80,269
	End of Year	32,715,042	31,653,262	30,212,453

SEGMENTS_OF_BUSINESS_Tables

SEGMENTS OF BUSINESS (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segments of Business	'
	Information about SJI’s operations in different reportable operating segments is presented below (in thousands):
		2013			2012			2011
	Operating Revenues:
	Gas Utility Operations	$	446,480		$	421,874		$	412,449
	Wholesale Energy Operations	831			17,429			68,370
	Retail Energy Operations:
	Retail Gas and Other Operations	107,748			80,486			100,977
	Retail Electric Operations	128,932			144,197			206,422
	On-Site Energy Production	43,551			38,308			39,919
	Appliance Service Operations	13,723			13,646			17,056
	Subtotal Retail Energy Operations	293,954			276,637			364,374
	Corporate & Services	31,286			29,318			25,325
	Subtotal	772,551			745,258			870,518
	Intersegment Sales	(41,130		)	(38,978		)	(41,958		)
	Total Operating Revenues	$	731,421		$	706,280		$	828,560
		2013			2012			2011
	Operating Income:
	Gas Utility Operations	$	105,822		$	101,762		$	102,663
	Wholesale Energy Operations	(37,720		)	(2,142		)	16,225
	Retail Energy Operations:
	Retail Gas and Other Operations	278			(1,204		)	478
	Retail Electric Operations	(98		)	12,683			1,755
	On-Site Energy Production	(2,011		)	(1,696		)	2,254
	Appliance Service Operations	2,995			(225		)	(1,539		)
	Subtotal Retail Energy Operations	1,164			9,558			2,948
	Corporate and Services	370			720			(229		)
	Total Operating Income	$	69,636		$	109,898		$	121,607
	Depreciation and Amortization:
	Gas Utility Operations	$	48,261		$	44,171		$	41,959
	Wholesale Energy Operations	206			229			253
	Retail Energy Operations:
	Retail Gas and Other Operations	93			78			33
	On-Site Energy Production	15,192			9,604			4,527
	Appliance Service Operations	261			308			322
	Subtotal Retail Energy Operations	15,546			9,990			4,882
	Corporate and Services	877			699			665
	Total Depreciation and Amortization	$	64,890		$	55,089		$	47,759
	Interest Charges:
	Gas Utility Operations	$	12,550		$	12,427		$	18,922
	Wholesale Energy Operations	417			229			54
	Retail Energy Operations:
	Retail Gas and Other Operations	280			139			186
	On-Site Energy Production	4,480			4,936			5,436
	Subtotal Retail Energy Operations	4,760			5,075			5,622
	Corporate and Services	6,004			4,219			2,648
	Subtotal	23,731			21,950			27,246
	Intersegment Borrowings	(4,906		)	(2,964		)	(3,168		)
	Total Interest Charges	$	18,825		$	18,986		$	24,078
	Income Taxes:
	Gas Utility Operations	$	34,833		$	33,711		$	34,281
	Wholesale Energy Operations	(15,070		)	(907		)	7,517
	Retail Energy Operations:
	Retail Gas and Other Operations	434			(144		)	511
	Retail Electric Operations	(40		)	5,181			717
	On-Site Energy Production	(40,755		)	(26,811		)	(22,258		)
	Appliance Service Operations	1,237			(75		)	1,480
	Subtotal Retail Energy Operations	(39,124		)	(21,849		)	(19,550		)
	Corporate and Services	347			524			254
	Total Income Taxes	$	(19,014	)	$	11,479		$	22,502
		2013			2012			2011
	Property Additions:
	Gas Utility Operations	$	173,099		$	156,990		$	141,918
	Wholesale Energy Operations	50			23			83
Retail Energy Operations:
Retail Gas and Other Operations	702			177			22
On-Site Energy Production	151,592			107,993			57,093
Appliance Service Operations	—			34			254
Subtotal Retail Energy Operations	152,294			108,204			57,369
Corporate and Services	3,061			4,308			605
Total Property Additions	$	328,504		$	269,525		$	199,975
	2013			2012
Identifiable Assets (See Note 1):
Gas Utility Operations	$	1,909,126		$	1,786,459
Wholesale Energy Operations	331,182			204,358
Retail Energy Operations:
Retail Gas and Other Operations	50,384			39,481
Retail Electric Operations	25,496			21,919
On-Site Energy Production	576,315			543,416
Appliance Service Operations	1,812			3,244
Subtotal Retail Energy Operations	654,007			608,060
Discontinued Operations	1,068			2,290
Corporate and Services	406,245			334,798
Intersegment Assets	(376,773		)	(304,525		)
Total Identifiable Assets	$	2,924,855		$	2,631,440

LEASES_Tables

LEASES (Tables)	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Schedule of Future Minimum Rental Payments	'
	Minimum future rentals to be received on non-cancelable leases of thermal energy generating property and equipment as of December 31, 2013 for each of the next five years and in the aggregate are (in thousands):
	Year ended December 31,
	2014	$	5,396
	2015	5,396
	2016	5,396
	2017	5,396
	2018	5,396
	Thereafter	45,418
	Total minimum future rentals	$	72,398

REGULATORY_ASSETS_REGULATORY_L1

REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Schedule of Regulatory Assets	'
	Regulatory Assets consisted of the following items (in thousands):
		December 31, 2013		December 31, 2012
	Environmental Remediation Costs:
	Expended - Net	$	29,945	$	37,892
	Liability for Future Expenditures	119,492		107,410
	Deferred Asset Retirement Obligation Costs	31,142		30,199
	Deferred Pension and Other Postretirement Benefit Costs	59,284		95,897
	Conservation Incentive Program Receivable	10,526		31,686
	Societal Benefit Costs Receivable	10,408		12,801
	Premium for Early Retirement of Debt	955		1,075
	Deferred Interest Rate Contracts	3,735		7,761
	Energy Efficiency Tracker	10,420		12,306
	Pipeline Supplier Service Charges	7,106		8,771
	Pipeline Integrity Cost	2,902		1,584
	Other Regulatory Assets	10,166		5,274
	Total Regulatory Assets	$	296,081	$	352,656
Schedule of Regulatory Liabilities	'
	Regulatory Liabilities consisted of the following items (in thousands):
		December 31, 2013		December 31, 2012
	Excess Plant Removal Costs	$	40,029	$	45,593
	Deferred Revenues - Net	19,067		10,924
	Other Regulatory Liabilities	1,853		—
	Total Regulatory Liabilities	$	60,949	$	56,517

PENSION_AND_OTHER_POSTRETIREME1

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	12 Months Ended
	Dec. 31, 2013
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
		2013				2012				2011
	Service Cost	$	5,421			$	4,533			$	3,918
	Interest Cost	9,439				9,622				9,524
	Expected Return on Plan Assets	(11,914		)		(10,341		)		(9,367		)
	Amortizations:
	Prior Service Cost	251				251				267
	Actuarial Loss	9,006				7,629				5,440
	Net Periodic Benefit Cost	12,203				11,694				9,782
	ERIP Costs	—				—				102
	Capitalized Benefit Costs	(5,002		)		(4,684		)		(3,661		)
	Total Net Periodic Benefit Expense	$	7,201			$	7,010			$	6,223
		Other Postretirement Benefits
		2013				2012				2011
	Service Cost	$	1,139			$	1,037			$	996
	Interest Cost	2,730				3,001				3,201
	Expected Return on Plan Assets	(2,378		)		(2,105		)		(2,248		)
	Amortizations:
	Prior Service Credits	(283		)		(283		)		(355		)
	Actuarial Loss	1,738				1,725				1,654
	Net Periodic Benefit Cost	2,946				3,375				3,248
	Capitalized Benefit Costs	(1,172		)		(1,340		)		(1,222		)
	Total Net Periodic Benefit Expense	$	1,774			$	2,035			$	2,026
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, 2012	$	61,811			$	26,435			$	31,766		$	4,745
	Amounts Arising during the Period:
	Net Actuarial Loss (Gain)	11,599				2,089				6,811			(446		)
	Amounts Amortized to Net Periodic Costs:
	Net Actuarial Loss	(4,490		)		(1,535		)		(3,103		)	(187		)
	Prior Service (Cost) Credit	(207		)		195				(43		)	83
	Balance at December 31, 2012	68,713				27,184				35,431			4,195
	Amounts Arising during the Period:
	Net Actuarial Gain	(20,554		)		(9,171		)		(4,173		)	(390		)
	Amounts Amortized to Net Periodic Costs:
	Net Actuarial Loss	(5,319		)		(1,555		)		(3,642		)	(177		)
	Prior Service (Cost) Credit	(208		)		194				(42		)	82
	Balance at December 31, 2013	$	42,632			$	16,652			$	27,574		$	3,710
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 2014 are as follows (in thousands):
		Pension Benefits				Other Postretirement Benefits
	Prior Service Costs	$	158			$	133
	Net Actuarial Loss	$	2,856			$	790
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 2014 are as follows (in thousands):
		Pension Benefits				Other Postretirement  Benefits
	Prior Service Costs	$	17			$	18
	Net Actuarial Loss	$	2,848			$	182
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
		2013				2012				2013			2012
	Change in Benefit Obligations:
	Benefit Obligation at Beginning of Year	$	224,389			$	194,990			$	68,779		$	64,451
	Service Cost	5,421				4,533				1,139			1,037
	Interest Cost	9,439				9,622				2,730			3,001
	Actuarial (Gain) Loss	(14,272		)		23,952				(6,361		)	3,861
	Retiree Contributions	—				—				388			342
	Benefits Paid	(8,582		)		(8,708		)		(4,320		)	(3,913		)
	Benefit Obligation at End of Year	$	216,395			$	224,389			$	62,355		$	68,779
	Change in Plan Assets:
	Fair Value of Plan Assets at Beginning of Year	$	150,160			$	116,718			$	36,032		$	31,896
	Actual Return on Plan Assets	22,556				15,935				5,621			4,263
	Employer Contributions	13,959				26,215				3,932			3,444
	Retiree Contributions	—				—				388			342
	Benefits Paid	(8,582		)		(8,708		)		(4,320		)	(3,913		)
	Fair Value of Plan Assets at End of Year	$	178,093			$	150,160			$	41,653		$	36,032
	Funded Status at End of Year:	$	(38,302	)		$	(74,229	)		$	(20,701	)	$	(32,747	)
	Amounts Related to Unconsolidated Affiliate	(7		)		161				365			375
	Accrued Net Benefit Cost at End of Year	$	(38,309	)		$	(74,068	)		$	(20,336	)	$	(32,372	)
	Amounts Recognized in the Statement of Financial Position Consist of:
	Current Liabilities	$	(1,275	)		$	(1,272	)		$	—		$	—
	Noncurrent Liabilities	(37,034		)		(72,796		)		(20,336		)	(32,372		)
	Net Amount Recognized at End of Year	$	(38,309	)		$	(74,068	)		$	(20,336	)	$	(32,372	)
	Amounts Recognized in Regulatory Assets Consist of:
	Prior Service Costs	$	634			$	842			$	952		$	758
	Net Actuarial Loss	41,998				67,871				15,700			26,426
		$	42,632			$	68,713			$	16,652		$	27,184
	Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):
	Prior Service Costs	$	69			$	111			$	150		$	68
	Net Actuarial Loss	27,505				35,320				3,560			4,127
		$	27,574			$	35,431			$	3,710		$	4,195
Schedule of Assumptions Used	'
	The weighted-average assumptions used to determine benefit obligations at December 31 were:
		Pension Benefits						Other Postretirement Benefits
		2013			2012			2013			2012
	Discount Rate	5.09	%		4.26	%		4.91	%		4.14	%
	Rate of Compensation Increase	3.5	%		3.25	%		3.5	%		3.25	%
	The weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 were:
		Pension Benefits									Other Postretirement Benefits
		2013			2012			2011			2013		2012			2011
	Discount Rate	4.26	%		5.03	%		5.78	%		4.14	%	4.92	%		5.55	%
	Expected Long-Term Return on Plan Assets	7.5	%		7.5	%		8	%		6.6	%	6.6	%		7	%
	Rate of Compensation Increase	3.25	%		3.25	%		3.25	%		3.25	%	3.25	%		3.25	%
Schedule of Health Care Cost Trend Rates	'
	The assumed health care cost trend rates at December 31 were:
		2013			2012
	Medical Care and Drug Cost Trend Rate Assumed for Next Year	7	%		7	%
	Dental Care Cost Trend Rate Assumed for Next Year	4.75	%		4.75	%
	Rate to which Cost Trend Rates are Assumed to Decline (the Ultimate Trend Rate)	4.75	%		4.75	%
	Year that the Rate Reaches the Ultimate Trend Rate	2023			2019
Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates	'
	Assumed health care cost trend rates 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	$	188			$	(149	)
	Effect on Postretirement Benefit Obligation	$	2,947			$	(2,483	)
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, 2012	$	12,274			$	—			$	3,212		$	5,460			$	20,946
	Actual return on plan assets:
	Relating to assets still held at the reporting date	1,219				—				(190		)	549				1,578
	Relating to assets sold during the period	(12		)		—				604			—				592
	Purchases, Sales and Settlements	(1,032		)		—				(410		)	—				(1,442		)
	Balance at December 31, 2012	12,449				—				3,216			6,009				21,674
	Actual return on plan assets:
	Relating to assets still held at the reporting date	(179		)		154				76			732				783
	Relating to assets sold during the period	17				—				431			—				448
	Purchases, Sales and Settlements	(965		)		4,000				(677		)	—				2,358
	Balance at December 31, 2013	$	11,322			$	4,154			$	3,046		$	6,741			$	25,263
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
	2014	$	9,210			$	4,438
	2015	$	9,842			$	4,574
	2016	$	10,289			$	4,660
	2017	$	10,801			$	4,743
	2018	$	12,256			$	4,767
	2019 - 2023	$	73,827			$	25,293
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, 2013 and 2012 by asset category are as follows (in thousands):
	Asset Category	Total				Level 1				Level 2			Level 3
	As of December 31, 2013
	Cash / Cash Equivalents:
	Common/Collective Trust Funds (a)	$	416			$	—			$	416		$	—
	STIF-Type Instrument (b)	1,177				—				1,177			—
	Equity securities:
	Common/Collective Trust Funds - U.S. (a)	51,837				—				51,837			—
	Common/Collective Trust Funds - International (a)	34,093				—				34,093			—
	U.S. Large-Cap (c)	11,661				11,661				—			—
	U.S. Mid-Cap (c)	4,135				4,135				—			—
	International (c)	3,664				3,664				—			—
	Fixed Income:
	Common/Collective Trust Funds (a)	45,847				—				45,847			—
	Guaranteed Insurance Contract (d)	11,322				—				—			11,322
	Hedge Funds (e)	4,154				—				—			4,154
	Other types of investments:
	Private Equity Fund (f)	3,046				—				—			3,046
	Common/Collective Trust Fund - Real Estate (g)	6,741				—				—			6,741
	Total	$	178,093			$	19,460			$	133,370		$	25,263
	Asset Category	Total				Level 1				Level 2			Level 3
	As of December 31, 2012
	Cash / Cash Equivalents:
	Common/Collective Trust Funds (a)	$	600			$	—			$	600		$	—
	STIF-Type Instrument (b)	1,056				—				1,056			—
	Equity securities:
	Common/Collective Trust Funds - U.S. (a)	42,373				—				42,373			—
	Common/Collective Trust Funds - International (a)	29,491				—				29,491			—
	U.S. Large-Cap (c)	8,963				8,963				—			—
	U.S. Mid-Cap (c)	5,275				5,275				—			—
	U.S. Small-Cap (c)	10				10				—			—
	International (c)	1,838				1,838				—			—
	Fixed Income:
	Common/Collective Trust Funds (a)	38,880				—				38,880			—
	Guaranteed Insurance Contract (d)	12,449				—				—			12,449
	Other types of investments:
	Private Equity Fund (f)	3,216				—				—			3,216
	Common/Collective Trust Fund - Real Estate (g)	6,009				—				—			6,009
	Total	$	150,160			$	16,086			$	112,400		$	21,674
	(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 day lag and, therefore, the value reported herein represents the market value as of September 30, 2013 and 2012, respectively.  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, 2013 and 2012 by asset category are as follows (in thousands):
	Asset Category	Total				Level 1				Level 2			Level 3
	As of December 31, 2013:
	Equity Securities:
	Common/Collective Trust Funds - U.S. (a)	$	13,098			$	—			$	13,098		$	—
	Common/Collective Trust Funds - International (a)	10,586				—				10,586			—
	Mutual Fund - U.S. Large-Cap (b)	2,969				2,969				—			—
	Fixed Income:
	Corporate Bonds (a)	15,000				—				15,000			—
	Total	$	41,653			$	2,969			$	38,684		$	—
	Asset Category	Total				Level 1				Level 2			Level 3
	As of December 31, 2012:
	Equity Securities:
	Common/Collective Trust Funds - U.S. (a)	$	10,992			$	—			$	10,992		$	—
	Common/Collective Trust Funds - International (a)	9,340				—				9,340			—
	Mutual Fund - U.S. Large-Cap (b)	2,563				2,563				—			—
	Fixed Income:
	Corporate Bonds (a)	13,137				—				13,137			—
	Total	$	36,032			$	2,563			$	33,469		$	—
	(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.

LINES_OF_CREDIT_Tables

LINES OF CREDIT (Tables)	12 Months Ended
	Dec. 31, 2013
Line of Credit Facility [Abstract]	'
Schedule of lines of credit	'
	Credit facilities and available liquidity as of December 31, 2013 were as follows (in thousands):
	Company	Total Facility		Usage		Available Liquidity		Expiration Date
	SJG:
	Commercial Paper Program/Revolving Credit Facility	$	200,000	$	65,500	$	134,500	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total SJG	210,000		65,500		144,500
	SJI:
	Revolving Credit Facility	400,000		315,200		84,800		February 2018 (A)
	Total SJI	400,000		315,200		84,800
	Total	$	610,000	$	380,700	$	229,300
	(A) Includes letters of credit outstanding in the amount of $26.8 million.

LONGTERM_DEBT_Tables

LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of Long-term Debt Instruments	'
	Outstanding Long-Term Debt at December 31 consisted of the following:
			2013			2012
	Long-Term Debt (A):
	South Jersey Gas Company:
	First Mortgage Bonds: (B)
	4.46%	Series due 2013 (C)	$	—		$	10,500
	5.03%	Series due 2013 (C)	—			14,500
	4.52%	Series due 2014	11,000			11,000
	5.12%	Series due 2014	10,000			10,000
	5.39%	Series due 2015	10,000			10,000
	5.44%	Series due 2016	10,000			10,000
	4.60%	Series due 2016	17,000			17,000
	4.66%	Series due 2017	15,000			15,000
	7.97%	Series due 2018	10,000			10,000
	7.12%	Series due 2018	20,000			20,000
	5.59%	Series due 2019	10,000			10,000
	3.00%	Series due 2024 (D)	50,000			50,000
	3.03%	Series due 2024 (D)	35,000			35,000
	3.63%	Series due 2025	10,000			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 (E)	50,000			—
	3.74%	Series due 2032	35,000			35,000
	5.55%	Series due 2033	32,000			32,000
	6.21%	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 (F)		25,000			25,000
	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 (H)
	2.39%	Series A 2012 Notes due 2015	64,000			64,000
	2.71%	Series B 2012 Notes due 2017	16,000			16,000
	3.46%	Series C 2012 Notes due 2022	35,000			35,000
	South Jersey Industries Term Loan at variable rates due 2015 (I)		50,000			—
	Total Long-Term Debt Outstanding		701,400			626,400
	Less Current Maturities		(21,000		)	(25,000		)
	Total Long-Term Debt		$	680,400		$	601,400
	(A)	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000.
	(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 July 2013, SJG called its $10.5 million, 4.46% MTN due July 2013 and $14.5 million, 5.027% MTN due September 2013.
	(D)	In September 2012, SJG issued $50.0 million of 3.00% aggregate principal amount of MTN's due September 2024. In November 2012, SJG issued $35.0 million of 3.03% aggregate principal amount of MTN's due November 2024.
	(E)	In November 2013, SJG issued $50.0 million of 4.01% aggregate principal amount of its MTN's due November 2030.
	(F)	These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2013 was 0.07%. Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August, 2015. These bonds contain no financial covenants.
	(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, 2013 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.08%, 0.18% and 0.08% respectively. The interest rate on all but $27.1 million of the bonds has been effectively fixed via interest rate swaps at 4.41% 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 August, 2015.
	(H)	In June 2012, the Company issued $115.0 million aggregate principal amount of long-term debt, consisting of the following: (a) $64.0 million aggregate principal amount of 2.39% Senior Notes due June 2015; (b) $16.0 million aggregate principal amount of 2.71% Senior Notes due June 2017; and (c) $35.0 million aggregate principal amount of 3.46% Senior Notes due June 2022.
	(I)	In October 2013, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2015. This agreement replaces existing facilities that were set to expire in November 2013.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2013
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):
		2013			2012
	Beginning of Year	$	112,098		$	94,160
	Accruals	22,821			30,349
	Expenditures	(11,490		)	(12,411		)
	End of Year	$	123,429		$	112,098

DERIVATIVE_INSTRUMENTS_Tables

DERIVATIVE INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of notional amounts of outstanding derivative positions	'
	As of December 31, 2013, SJI's active interest rate swaps were as follows:
	Notional Amount				Fixed Interest Rate		Start Date		Maturity		Type of Debt		Obligor
	$	3,900,000			4.80%		12/1/04		12/1/14		Taxable		Marina
	$	8,000,000			4.78%		11/12/04		11/12/14		Taxable		Marina
	$	14,500,000			3.91%		3/17/06		1/15/26		Tax-exempt		Marina
	$	500,000			3.91%		3/17/06		1/15/26		Tax-exempt		Marina
	$	330,000			3.91%		3/17/06		1/15/26		Tax-exempt		Marina
	$	7,100,000			4.90%		2/1/06		2/1/16		Taxable		Marina
	$	12,500,000			3.43%		12/1/06		2/1/36		Tax-exempt		SJG
	$	12,500,000			3.43%		12/1/06		2/1/36		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		2013								2012
			Assets				Liabilities				Assets				Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current		$	56,327			$	77,993			$	24,242			$	23,828
	Derivatives – Energy Related – Non-Current		26,451				22,131				12,297				5,403
	Interest rate contracts:
	Derivatives - Other		—				6,676				—				13,462
	Total derivatives not designated as hedging instruments under GAAP		82,778				106,800				36,539				42,693
	Total Derivatives		$	82,778			$	106,800			$	36,539			$	42,693
Offsetting arrangements	'
	As of December 31, 2013 and 2012, information related to these offsetting arrangements were as follows (in thousands):
	As of December 31, 2013
	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		82,778			—			$	82,778			(28,082	)	(A)	(498	)	$	54,198
	Derivatives - Energy Related Liabilities		(100,124	)		—			$	(100,124	)		28,082		(B)	29,639		$	(42,403	)
	Derivatives - Other		(6,676	)		—			$	(6,676	)		—			—		$	(6,676	)
	As of December 31, 2012
	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		36,539			—			$	36,539			(12,975	)	(A)	—		$	23,564
	Derivatives - Energy Related Liabilities		(29,231	)		—			$	(29,231	)		12,975		(B)	6,347		$	(9,909	)
	Derivatives - Other		(13,462	)		—			$	(13,462	)		—			—		$	(13,462	)
	(A) The balances at December 31, 2013 and 2012 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at December 31, 2013 and 2012 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 consolidated statements of income and comprehensive income for the year ended December 31 is as follows (in thousands):
	Derivatives in Cash Flow Hedging Relationships		2013				2012				2011
	Interest Rate Contracts:
	Losses recognized in AOCL on effective portion		$	—			$	(752	)		$	(2,773	)
	Losses reclassified from AOCL into income (a)		$	(448	)		$	(594	)		$	(1,435	)
	Losses recognized in income on ineffective portion (a)		—				—				—
	(a) Included in Interest Charges
	Derivatives Not Designated as Hedging Instruments under GAAP		2013				2012				2011
	(Losses) gains on energy related commodity contracts (a)		$	(25,823	)		$	(193	)		$	5,377
	Gains (losses) on interest rate contracts (b)		2,760				660				(149		)
	Total		$	(23,063	)		$	467			$	5,228
	(a)  Included in Operating Revenues - Non Utility
	(b)  Included in Interest Charges

FAIR_VALUE_OF_FINANCIAL_ASSETS1

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2013
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, 2013	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,716			$	8,716			$	—	$	—
	Derivatives – Energy Related Assets (B)	82,778				4,385				27,182		51,211
		$	91,494			$	13,101			$	27,182	$	51,211
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	100,124			$	4,236			$	52,772	$	43,116
	Derivatives – Other (C)	6,676				—				6,676		—
		$	106,800			$	4,236			$	59,448	$	43,116
	As of December 31, 2012	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	7,538			$	787			$	6,751	$	—
	Derivatives – Energy Related Assets (B)	36,539				9,404				16,205		10,930
		$	44,077			$	10,191			$	22,956	$	10,930
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	29,231			$	5,399			$	15,664	$	8,168
	Derivatives – Other (C)	13,462				—				13,462		—
		$	42,693			$	5,399			$	29,126	$	8,168
	(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, 2013						Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets			Liabilities
	Forward Contract - Natural Gas	$	41,444		$	36,043		Discounted Cash Flow	Forward price (per dt)	$(1.75) - $6.05 [$(0.79)]
	Forward Contract - Electric	$	9,767		$	7,073		Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [54.55%]
									Fixed electric load profile (off-peak)	0.00% - 91.94% [45.45%]
	Type	Fair Value at December 31, 2012				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets		Liabilities
	Forward Contract - Natural Gas	4,340		4,986		Discounted Cash Flow	Forward price (per dt)	$(0.35) - $2.92 [$(0.12)]
	Forward Contract - Electric	6,590		3,182		Discounted Cash Flow	Fixed electric load profile (on-peak)	21.62% - 100.00% [53.64%]
							Fixed electric load profile (off-peak)	0.00% - 78.38% [46.36%]
Changes in fair value of significant unobservable inputs	'
	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
			Year Ended December 31, 2013
	Balance at January 1, 2013		$	2,762
	Other changes in fair value from continuing and new contracts, net		1,573
	Transfers in/(out) of Level 3 (A)		2,748
	Settlements		1,012
	Balance at December 31, 2013		$	8,095
	(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, 2013, $2.7 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data.
			Year Ended December 31, 2012
	Balance at January 1, 2012		$	(5,958	)
	Other changes in fair value from continuing and new contracts, net		2,902
	Settlements		5,818
	Balance at December 31, 2012		$	2,762

ACCUMULATED_OTHER_COMPREHENSIV1

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	12 Months Ended
	Dec. 31, 2013
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, 2013 (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, 2013 (a)	$	(23,437	)	$	(2,962	)	$	294		$	(5,000	)	$	(31,105	)
	Other comprehensive income before reclassifications	2,699						592						3,291
	Amounts reclassified from AOCL (b)	2,235			265			(489		)	5,043			7,054
	Net current period other comprehensive income	4,934			265			103			5,043			10,345
	Balance at December 31, 2013 (a)	$	(18,503	)	$	(2,697	)	$	397		$	43		$	(20,760	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
	The following table provides details about reclassifications out of AOCL for the year ended December 31, 2013 (in thousands):
		Amounts Reclassified from AOCL			Affected Line Item in the Condensed Consolidated Statements of Income
		For the Year Ended December 31, 2013
	Actuarial Loss on Postretirement Benefits	$	3,779		Operating Expenses: Operations
	Income Taxes	(1,544		)	Income Taxes (a)
		$	2,235
	Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	448		Interest Charges
	Income Taxes	(183		)	Income Taxes (a)
		$	265
	Unrealized Loss on Available-for-Sale Securities	$	(828	)	Other Income
	Income Taxes	339			Income Taxes (a)
		$	(489	)
	Income of Affiliated Companies	$	8,515		Equity in Loss of Affiliated Companies
	Income Taxes	(3,472		)	Income Taxes (a)
		$	5,043
	Losses from reclassifications for the period net of tax	$	7,054

Quarterly_Financial_Data_Unaud1

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of quarterly results	'
		2013 Quarter Ended												2012 Quarter Ended
		31-Mar			30-Jun			Sept. 30			Dec. 31			31-Mar			30-Jun			Sept. 30			Dec. 31
	Operating Revenues	$	255,631		$	122,592		$	128,808		$	224,390		$	274,832		$	121,913		$	111,977		$	197,558
	Expenses:
	Cost of Sales - (Excluding depreciation)	152,301			87,827			89,160			139,703			156,868			69,519			70,549			120,866
	Operations and Maintenance Including Fixed Charges	52,226			47,114			47,789			54,674			46,071			45,467			45,970			50,072
	Income Taxes	7,772			(11,632		)	(5,533		)	(9,621		)	15,884			(1,072		)	(2,576		)	(757		)
	Energy and Other Taxes	3,833			1,664			1,458			2,861			3,878			1,865			1,494			2,749
	Total Expenses	216,132			124,973			132,874			187,617			222,701			115,779			115,437			172,930
	Other Income and Expense	3,838			3,297			2,845			2,584			2,080			4,698			5,624			941
	Income (Loss) from Continuing Operations	43,337			916			(1,221		)	39,357			54,211			10,832			2,164			25,569
	Loss from Discontinued Operations  -  (Net of tax benefit)	(471		)	(28		)	(200		)	(97		)	(136		)	(498		)	(151		)	(383		)
	Net Income (Loss)	$	42,866		$	888		$	(1,421	)	$	39,260		$	54,075		$	10,334		$	2,013		$	25,186
	Basic Earnings Per Common Share:
	Continuing Operations	$	1.37		$	0.03		$	(0.04	)	$	1.22		$	1.79		$	0.36		$	0.07		$	0.81
	Discontinued Operations	(0.02		)	—			—			—			—			(0.02		)	(0.01		)	(0.01		)
	Basic Earnings Per Common Share	$	1.35		$	0.03		$	(0.04	)	$	1.22		$	1.79		$	0.34		$	0.07		$	0.8
	Average Shares of Common Stock Outstanding - Basic	31,757			31,949			31,984			32,259			30,249			30,393			30,861			31,465
	Diluted Earnings Per Common Share:
	Continuing Operations	$	1.36		$	0.03		$	(0.04	)	$	1.22		$	1.79		$	0.36		$	0.07		$	0.81
	Discontinued Operations	(0.01		)	—			—			—			(0.01		)	(0.02		)	(0.01		)	(0.01		)
	Diluted Earnings Per Common Share	$	1.35		$	0.03		$	(0.04	)	$	1.22		$	1.78		$	0.34		$	0.07		$	0.8
	Average Shares of Common Stock Outstanding - Diluted	31,811			32,012			31,984			32,306			30,323			30,472			30,945			31,547
	The sum of the quarters for 2013 and 2012 do not equal the year's total due to rounding.

SUMMARY_OF_SIGNIFICANT_ACCOUNT3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Schedule of Accounting Policies [Line Items]	'		'		'
Equity investment impairments	$0		$0		$0
TEFA and PUA included in both utility revenue and cost of sales	5,200,000		6,000,000		8,000,000
Decrease in TEFA revenue based tax rate	25.00%		25.00%		'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'		'		'
AROs as of January 1,	39,385,000		29,430,000		'
Accretion	1,530,000		1,872,000		'
Additions	743,000		1,438,000		'
Settlements	-1,630,000		-1,603,000		'
Revisions in Estimated Cash Flows	1,659,000	[1]	8,248,000	[1]	'
ARO's as of December 31,	41,687,000		39,385,000		29,430,000
Composite annual rate for all depreciable utility property	2.30%		2.40%		2.30%
Useful life	'50 years		'		'
Interest capitalized	8,700,000		6,500,000		1,200,000
Impairment of nonutility property and equipment and other noncurrent assets	0		1,100,000		0
Amount of costs related to interests in proved and unproved properties in Pennsylvania, net of amortization	8,900,000		9,000,000		'
Shares of treasury stock held	148,890		145,414		'
Marina Energy LLC [Member]	'		'		'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'		'		'
Impairment of long-lived assets	'		$2,400,000		'
[1]	The revision in estimated cash flows in 2013 reflects an increase in the inflation rate used to determine the ARO settlement amount. In 2012, the revision in estimated cash flows reflected increases in the contractual cost as well as changes in the discount rates used to determine the ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.

STOCKBASED_COMPENSATION_PLAN_D

STOCK-BASED COMPENSATION PLAN (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Number of shares in the aggregate that may be issued under the 1997 Stock-Based Compensation Plan	2,000,000		'	'
Number of options granted	0		0	0
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	150.00%		'	'
Fair value per share (in dollars per share)	$50.73		$51.29	'
Expected volatility, measurement period	'3 years		'	'
Net Expense	$2,764,000		$2,761,000	$2,292,000
Capitalized	-237,000		-231,000	-218,000
Unrecognized compensation cost of awards granted under the plan	2,500,000		'	'
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	'1 year 8 months 12 days		'	'
Weighted Average Fair Value	'		'	'
Nonvested Shares Outstanding, beginning balance (in dollars per share)	$51.29		'	'
Granted (in dollars per share)	$48.49		'	'
Vested (in dollars per share)	$49.20	[1]	'	'
Cancelled/Forfeited (in dollars per share)	$50.28		'	'
Nonvested Shares Outstanding, ending balance (in dollars per share)	$50.73		$51.29	'
Cost [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Net Expense	3,001,000		2,992,000	2,510,000
Officers and Key Employees [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Number of awards granted	56,464		40,955	40,711
Vesting period of shares	'3 years		'3 years	'3 years
The range of the actual amount of shares that ultimately vest of the original share units granted (in hundredths)	'0% to 150%		'	'
Shares outstanding (in shares)	94,192		81,005	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested shares outstanding, beginning balance (in shares)	81,005		'	'
Granted (in shares)	56,464		40,955	40,711
Vested (in shares)	-39,720	[1]	'	'
Cancelled/Forfeited (in shares)	-3,557		'	'
Nonvested shares outstanding, ending balance (in shares)	94,192		81,005	'
Weighted Average Fair Value	'		'	'
Shares expected to be awarded to officers and key employees	0		'	'
Number of shares awarded during the period	66,077		33,322	69,271
Market value of shares awarded	3,300,000		1,900,000	3,700,000
Officers and Key Employees [Member] | Cost [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Net Expense	2,236,000		2,096,000	1,852,000
Officers and Key Employees [Member] | Jan. 2012 - TSR [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares outstanding (in shares)	19,810		'	'
Fair value per share (in dollars per share)	$51.23		'	'
Expected volatility	22.50%		'	'
Risk-free interest rate	0.43%		'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested shares outstanding, ending balance (in shares)	19,810		'	'
Weighted Average Fair Value	'		'	'
Nonvested Shares Outstanding, ending balance (in dollars per share)	$51.23		'	'
Officers and Key Employees [Member] | Jan. 2012 - EPS [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares outstanding (in shares)	19,810		'	'
Fair value per share (in dollars per share)	$56.93		'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested shares outstanding, ending balance (in shares)	19,810		'	'
Weighted Average Fair Value	'		'	'
Nonvested Shares Outstanding, ending balance (in dollars per share)	$56.93		'	'
Officers and Key Employees [Member] | Jan. 2013 - TSR [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares outstanding (in shares)	27,286		'	'
Fair value per share (in dollars per share)	$44.38		'	'
Expected volatility	21.10%		'	'
Risk-free interest rate	0.40%		'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested shares outstanding, ending balance (in shares)	27,286		'	'
Weighted Average Fair Value	'		'	'
Nonvested Shares Outstanding, ending balance (in dollars per share)	$44.38		'	'
Officers and Key Employees [Member] | Jan. 2013 - EPS [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares outstanding (in shares)	27,286		'	'
Fair value per share (in dollars per share)	$51.18		'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested shares outstanding, ending balance (in shares)	27,286		'	'
Weighted Average Fair Value	'		'	'
Nonvested Shares Outstanding, ending balance (in dollars per share)	$51.18		'	'
Directors [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Number of awards granted	12,285		9,904	12,220
Vesting period of shares	'12 months		'12 months	'3 years
Percent of shares vested, Directors	100.00%		'	'
Shares outstanding (in shares)	19,617		27,688	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested shares outstanding, beginning balance (in shares)	27,688		'	'
Granted (in shares)	12,285		9,904	12,220
Vested (in shares)	-20,356	[1]	'	'
Cancelled/Forfeited (in shares)	0		'	'
Nonvested shares outstanding, ending balance (in shares)	19,617		27,688	'
Weighted Average Fair Value	'		'	'
Market value of shares awarded	600,000		600,000	600,000
Directors [Member] | Cost [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Net Expense	$765,000		$896,000	$658,000
Directors [Member] | Jan. 2011 [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares outstanding (in shares)	7,332		'	'
Fair value per share (in dollars per share)	$52.94		'	'
Expected volatility	0.00%		'	'
Risk-free interest rate	0.00%		'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested shares outstanding, ending balance (in shares)	7,332		'	'
Weighted Average Fair Value	'		'	'
Nonvested Shares Outstanding, ending balance (in dollars per share)	$52.94		'	'
Directors [Member] | Jan. 2013 [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares outstanding (in shares)	12,285		'	'
Fair value per share (in dollars per share)	$51.74		'	'
Expected volatility	0.00%		'	'
Risk-free interest rate	0.00%		'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested shares outstanding, ending balance (in shares)	12,285		'	'
Weighted Average Fair Value	'		'	'
Nonvested Shares Outstanding, ending balance (in dollars per share)	$51.74		'	'
Stock Appreciation Rights (SARs) [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Number of awards granted	0		0	0
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Granted (in shares)	0		0	0
[1]	Performance targets during the three-year vesting period were not attained for the January 2011 grant. As a result, no shares will be awarded in 2014.

DISCONTINUED_OPERATIONS_AND_AF2

DISCONTINUED OPERATIONS AND AFFILIATIONS (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Loss before Income Taxes: [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Income Tax Benefits	'	'	'	'	'	'	'	'	$426	$629	$302
Loss from Discontinued Operations - Net	-97	-200	-28	-471	-383	-151	-498	-136	-796	-1,168	-568
Earnings Per Common Share from Discontinued Operations - Net [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Basic (in dollars per share)	$0	$0	$0	($0.02)	($0.01)	($0.01)	($0.02)	$0	($0.03)	($0.04)	($0.02)
Diluted (in dollars per share)	$0	$0	$0	($0.01)	($0.01)	($0.01)	($0.02)	($0.01)	($0.02)	($0.04)	($0.02)
Sand Mining [Member]	'	'	'	'	'	'	'	'	'	'	'
Loss before Income Taxes: [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Loss before Income Taxes	'	'	'	'	'	'	'	'	-406	-1,396	-169
Fuel Oil [Member]	'	'	'	'	'	'	'	'	'	'	'
Loss before Income Taxes: [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Loss before Income Taxes	'	'	'	'	'	'	'	'	($816)	($401)	($701)

DISCONTINUED_OPERATIONS_AND_AF3

DISCONTINUED OPERATIONS AND AFFILIATIONS 2 (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 30, 2007

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 30, 2012

LVE Energy Partners [Member]

Equity Method Investee [Member]

Energenic US LLC [Member]

Energenic US LLC [Member]

Energenic US LLC [Member]

LVE Energy Partners, LLC (LVE) [Member]

LVE Energy Partners, LLC (LVE) [Member]

Potato Creek, LLC (Potato Creek) [Member]

The Energy Network, LLC, TEN Companies and CEN Power I, LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

LVE Energy Partners [Member]

Affiliations [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Equity interest

'

'

'

50.00%

50.00%

'

50.00%

50.00%

50.00%

'

30.00%

'

Advances

'

'

'

'

'

'

'

'

'

'

'

$35,400,000

Proceeds from sale of interest in joint venture

'

'

'

'

'

'

'

'

'

57,900,000

'

'

Investments in unconsolidated affiliates

9,600,000

94,000,000

14,600,000

'

'

'

'

'

'

'

'

'

Notes Receivable - affiliate

48,800,000

156,700,000

'

'

'

'

'

'

'

'

'

'

Interest accrual on secured notes receivable

'

'

'

'

'

7.50%

'

'

'

'

'

'

Repayment period, latest date

'2025

'

'

'

'

'

'

'

'

'

'

'

Net asset - included in investment in affiliates and other noncurrent liabilities

78,300,000

'

'

'

'

'

'

'

'

'

'

'

Combined equity contributions and the notes receivable - affiliate

127,100,000

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Current assets

57,725,000

57,711,000

'

'

'

'

'

'

'

'

'

'

Noncurrent assets

494,933,000

759,996,000

'

'

'

'

'

'

'

'

'

'

Current liabilities

60,355,000

211,628,000

'

'

'

'

'

'

'

'

'

'

Noncurrent liabilities

341,548,000

460,560,000

'

'

'

'

'

'

'

'

'

'

Revenues

178,026,000

148,009,000

95,647,000

'

'

'

'

'

'

'

'

'

Cost of sales

91,228,000

71,141,000

64,181,000

'

'

'

'

'

'

'

'

'

Income from continuing operations

6,229,000

5,795,000

1,522,000

'

'

'

'

'

'

'

'

'

Net Income

$6,229,000

$5,795,000

$1,522,000

'

'

'

'

'

'

'

'

'

INCOME_TAXES_Details

INCOME TAXES (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Expense (Benefit), Continuing Operations, Income Tax Reconciliation [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Tax at Statutory Rate	'	'	'	'	'	'	'	'	$22,181,000	$36,490,000	$39,326,000
Increase (Decrease) Resulting from:	'	'	'	'	'	'	'	'	'	'	'
State Income Taxes	'	'	'	'	'	'	'	'	971,000	5,857,000	6,763,000
ESOP	'	'	'	'	'	'	'	'	-1,176,000	-1,141,000	-1,063,000
Amortization of Investment Tax Credits	'	'	'	'	'	'	'	'	-258,000	-287,000	-302,000
Amortization of Flowthrough Depreciation	'	'	'	'	'	'	'	'	0	0	526,000
AFUDC	'	'	'	'	'	'	'	'	-916,000	-1,048,000	-729,000
Investment and Other Tax Credits	'	'	'	'	'	'	'	'	-38,179,000	-26,574,000	-21,927,000
Other - Net	'	'	'	'	'	'	'	'	-1,637,000	-1,818,000	-92,000
Income Taxes: Continuing Operations	'	'	'	'	'	'	'	'	-19,014,000	11,479,000	22,502,000
Income Taxes: Discontinued Operations	'	'	'	'	'	'	'	'	-426,000	-629,000	-302,000
Net Income Taxes	-9,621,000	-5,533,000	-11,632,000	7,772,000	-757,000	-2,576,000	-1,072,000	15,884,000	-19,440,000	10,850,000	22,200,000
Current:	'	'	'	'	'	'	'	'	'	'	'
Federal	'	'	'	'	'	'	'	'	-273,000	-8,761,000	-844,000
State	'	'	'	'	'	'	'	'	3,066,000	221,000	345,000
Total Current	'	'	'	'	'	'	'	'	2,793,000	-8,540,000	-499,000
Deferred:	'	'	'	'	'	'	'	'	'	'	'
Federal	'	'	'	'	'	'	'	'	-19,978,000	11,515,000	13,244,000
State	'	'	'	'	'	'	'	'	-1,571,000	8,791,000	10,059,000
Total Deferred	'	'	'	'	'	'	'	'	-21,549,000	20,306,000	23,303,000
Investment Tax Credits	'	'	'	'	'	'	'	'	-258,000	-287,000	-302,000
Income Taxes: Continuing Operations	'	'	'	'	'	'	'	'	-19,014,000	11,479,000	22,502,000
Income Taxes: Discontinued Operations	'	'	'	'	'	'	'	'	-426,000	-629,000	-302,000
Net Income Taxes	-9,621,000	-5,533,000	-11,632,000	7,772,000	-757,000	-2,576,000	-1,072,000	15,884,000	-19,440,000	10,850,000	22,200,000
Annual amortization rate of investment tax credits	'	'	'	'	'	'	'	'	3.00%	'	'
Current:	'	'	'	'	'	'	'	'	'	'	'
Current Deferred Tax (Asset) Liability - Net	-30,609,000	'	'	'	10,812,000	'	'	'	-30,609,000	10,812,000	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Noncurrent Deferred Tax Liability - Net	319,368,000	'	'	'	289,489,000	'	'	'	319,368,000	289,489,000	'
Accrued interest and penalties on unrecognized tax benefits	600,000	'	'	'	600,000	'	'	'	600,000	600,000	700,000
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'	'	'	'	'	'	'	'	'	'	'
Balance at January 1,	'	'	'	503,000	'	'	'	736,000	503,000	736,000	793,000
Increase as a result of tax positions taken in prior years	'	'	'	'	'	'	'	'	44,000	108,000	119,000
Decrease due to a lapse in the statute of limitations	'	'	'	'	'	'	'	'	0	-341,000	-90,000
Settlements	'	'	'	'	'	'	'	'	0	0	-86,000
Balance at December 31,	547,000	'	'	'	503,000	'	'	'	547,000	503,000	736,000
Internal Revenue Service (IRS) [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	317,700,000	'	'	'	'	'	'	'	317,700,000	'	'
Tax credit carryforwards	116,500,000	'	'	'	'	'	'	'	116,500,000	'	'
Alternative minimum tax credits	1,200,000	'	'	'	'	'	'	'	1,200,000	'	'
Internal Revenue Service (IRS) [Member] | 2030 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Tax credit carryforwards	11,600,000	'	'	'	'	'	'	'	11,600,000	'	'
Internal Revenue Service (IRS) [Member] | 2031 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	163,900,000	'	'	'	'	'	'	'	163,900,000	'	'
Tax credit carryforwards	26,600,000	'	'	'	'	'	'	'	26,600,000	'	'
Internal Revenue Service (IRS) [Member] | 2032 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	43,700,000	'	'	'	'	'	'	'	43,700,000	'	'
Tax credit carryforwards	32,100,000	'	'	'	'	'	'	'	32,100,000	'	'
Internal Revenue Service (IRS) [Member] | 2033 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	110,100,000	'	'	'	'	'	'	'	110,100,000	'	'
Tax credit carryforwards	46,200,000	'	'	'	'	'	'	'	46,200,000	'	'
State and Local Jurisdiction [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	105,400,000	'	'	'	'	'	'	'	105,400,000	'	'
State and Local Jurisdiction [Member] | 2031 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	45,900,000	'	'	'	'	'	'	'	45,900,000	'	'
State and Local Jurisdiction [Member] | 2032 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	19,400,000	'	'	'	'	'	'	'	19,400,000	'	'
State and Local Jurisdiction [Member] | 2033 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	40,100,000	'	'	'	'	'	'	'	40,100,000	'	'
Classified as Current [Member]	'	'	'	'	'	'	'	'	'	'	'
Current:	'	'	'	'	'	'	'	'	'	'	'
Net Operating Loss Carryforward	-26,800,000	'	'	'	-2,586,000	'	'	'	-26,800,000	-2,586,000	'
Derivatives / Unrealized Gain	-8,608,000	'	'	'	257,000	'	'	'	-8,608,000	257,000	'
Conservation Incentive Program	4,631,000	'	'	'	13,942,000	'	'	'	4,631,000	13,942,000	'
Budget Billing - Customer Accounts	1,152,000	'	'	'	1,033,000	'	'	'	1,152,000	1,033,000	'
Provision for Uncollectibles	-1,994,000	'	'	'	-1,883,000	'	'	'	-1,994,000	-1,883,000	'
Other	1,010,000	'	'	'	49,000	'	'	'	1,010,000	49,000	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Derivatives / Unrealized Gain	-8,608,000	'	'	'	257,000	'	'	'	-8,608,000	257,000	'
Net Operating Loss Carryforward	-26,800,000	'	'	'	-2,586,000	'	'	'	-26,800,000	-2,586,000	'
Classified as Noncurrent [Member]	'	'	'	'	'	'	'	'	'	'	'
Current:	'	'	'	'	'	'	'	'	'	'	'
Net Operating Loss Carryforward	-90,818,000	'	'	'	-79,217,000	'	'	'	-90,818,000	-79,217,000	'
Derivatives / Unrealized Gain	2,149,000	'	'	'	-82,000	'	'	'	2,149,000	-82,000	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Book versus Tax Basis of Property	476,039,000	'	'	'	395,322,000	'	'	'	476,039,000	395,322,000	'
Deferred Gas Costs - Net	1,330,000	'	'	'	3,325,000	'	'	'	1,330,000	3,325,000	'
Environmental	13,017,000	'	'	'	16,006,000	'	'	'	13,017,000	16,006,000	'
Deferred Regulatory Costs	13,665,000	'	'	'	15,374,000	'	'	'	13,665,000	15,374,000	'
Deferred State Tax	-17,949,000	'	'	'	-17,924,000	'	'	'	-17,949,000	-17,924,000	'
Investment Tax Credit Basis Gross-Up	-185,000	'	'	'	-318,000	'	'	'	-185,000	-318,000	'
Deferred Pension & Other Post Retirement Benefits	24,218,000	'	'	'	39,174,000	'	'	'	24,218,000	39,174,000	'
Pension & Other Post Retirement Benefits	-17,777,000	'	'	'	-33,739,000	'	'	'	-17,777,000	-33,739,000	'
Deferred Revenues	-9,593,000	'	'	'	-9,367,000	'	'	'	-9,593,000	-9,367,000	'
Derivatives / Unrealized Gain	2,149,000	'	'	'	-82,000	'	'	'	2,149,000	-82,000	'
Net Operating Loss Carryforward	-90,818,000	'	'	'	-79,217,000	'	'	'	-90,818,000	-79,217,000	'
Investment and Other Tax Credits	-117,726,000	'	'	'	-71,547,000	'	'	'	-117,726,000	-71,547,000	'
Equity In Loss Of Affiliated Companies	37,764,000	'	'	'	30,707,000	'	'	'	37,764,000	30,707,000	'
Other	$5,234,000	'	'	'	$1,775,000	'	'	'	$5,234,000	$1,775,000	'

PREFERRED_STOCK_Details

PREFERRED STOCK (Details)	Dec. 31, 2013
Equity [Abstract]	'
Preferred Stock, shares authorized	2,500,000

COMMON_STOCK_Details

COMMON STOCK (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'
Beginning balance	31,653,262	30,212,453	29,872,825
New issues during period [Abstract]	'	'	'
Dividend Reinvestment Plan	983,417	1,397,583	259,359
Stock-Based Compensation Plan	78,363	43,226	80,269
Ending balance	32,715,042	31,653,262	30,212,453
Par value of common stock (in dollars per share)	$1.25	$1.25	'
Net excess over par value recorded in premium on common stock (in dollars)	$55.20	$72.50	$16
Incremental shares included in diluted earnings per share	57,760	79,475	86,031
Dividend per share (in dollars per share)	$1.80	$1.65	$1.50
Equity capital raised through Dividend Reinvestment Plan (in dollars)	$54	$70.20	'

FINANCIAL_INSTRUMENTS_Details

FINANCIAL INSTRUMENTS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
		Fair Value, Inputs, Level 1 [Member]	Fair Value, Inputs, Level 1 [Member]	Fair Value, Inputs, Level 2 [Member]	Fair Value, Inputs, Level 2 [Member]
				South Jersey Gas Company [Member]	South Jersey Gas Company [Member]
				Financing Receivable [Member]	Financing Receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'	'	'	'
Restricted investments held in escrow	'	$1.30	$1.30	'	'
Margin accounts with selected counterparties to support risk management activities	'	41.8	16.6	'	'
Receivable With Imputed Interest, Term	'5 years	'	'	'	'
Long-term receivables, net of unamortized discount	'	'	'	15	13.6
Imputed interest on long term receivables	'	'	'	$1.30	'

FINANCIAL_INSTRUMENTS_2_Detail

FINANCIAL INSTRUMENTS 2 (Details) (Derivatives Energy Related Assets [Member], Supplier Concentration Risk [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Derivatives Energy Related Assets [Member] | Supplier Concentration Risk [Member]	'
Concentration Risk [Line Items]	'
Amount of derivatives - energy related assets with single retail counterparty	$28.10
Percentage of derivatives - energy related assets with a single retail counterparty (in hundredths)	33.90%

FINANCIAL_INSTRUMENTS_3_Detail

FINANCIAL INSTRUMENTS 3 (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Mar. 31, 2013
Schedule of Equity Method Investments [Line Items]	'		'		'
Finance obligation to ACB Energy Partners LLC	$20,656,000		$21,646,000		'
Carrying amount of long-term debt	701,400,000	[1]	626,400,000	[1]	'
Marina Energy LLC [Member] | Energenic US LLC [Member]	'		'		'
Schedule of Equity Method Investments [Line Items]	'		'		'
Equity interest of Marina in Energenic	50.00%		'		50.00%
Other construction costs	23,700,000		23,600,000		'
Fair Value, Inputs, Level 2 [Member]	'		'		'
Schedule of Equity Method Investments [Line Items]	'		'		'
Estimated fair value of long-term debt	713,200,000		682,300,000		'
Carrying amount of long-term debt	$701,400,000		$626,400,000		'
[1]	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000.

SEGMENTS_OF_BUSINESS_Details

SEGMENTS OF BUSINESS (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	$224,390	$128,808	$122,592	$255,631	$197,558	$111,977	$121,913	$274,832	$731,421	$706,280	$828,560
Operating Income (Loss)	'	'	'	'	'	'	'	'	69,636	109,898	121,607
Depreciation and Amortization	'	'	'	'	'	'	'	'	64,890	55,089	47,759
Interest Charges	'	'	'	'	'	'	'	'	18,825	18,986	24,078
Income Taxes	'	'	'	'	'	'	'	'	-19,014	11,479	22,502
Property Additions	'	'	'	'	'	'	'	'	328,504	269,525	199,975
Identifiable Assets	2,924,855	'	'	'	2,631,440	'	'	'	2,924,855	2,631,440	'
Operating Segments [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	772,551	745,258	870,518
Interest Charges	'	'	'	'	'	'	'	'	23,731	21,950	27,246
Operating Segments [Member] | Gas Utility Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	446,480	421,874	412,449
Operating Income (Loss)	'	'	'	'	'	'	'	'	105,822	101,762	102,663
Depreciation and Amortization	'	'	'	'	'	'	'	'	48,261	44,171	41,959
Interest Charges	'	'	'	'	'	'	'	'	12,550	12,427	18,922
Income Taxes	'	'	'	'	'	'	'	'	34,833	33,711	34,281
Property Additions	'	'	'	'	'	'	'	'	173,099	156,990	141,918
Identifiable Assets	1,909,126	'	'	'	1,786,459	'	'	'	1,909,126	1,786,459	'
Operating Segments [Member] | Wholesale Energy Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	831	17,429	68,370
Operating Income (Loss)	'	'	'	'	'	'	'	'	-37,720	-2,142	16,225
Depreciation and Amortization	'	'	'	'	'	'	'	'	206	229	253
Interest Charges	'	'	'	'	'	'	'	'	417	229	54
Income Taxes	'	'	'	'	'	'	'	'	-15,070	-907	7,517
Property Additions	'	'	'	'	'	'	'	'	50	23	83
Identifiable Assets	331,182	'	'	'	204,358	'	'	'	331,182	204,358	'
Operating Segments [Member] | Retail Energy Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	293,954	276,637	364,374
Operating Income (Loss)	'	'	'	'	'	'	'	'	1,164	9,558	2,948
Depreciation and Amortization	'	'	'	'	'	'	'	'	15,546	9,990	4,882
Interest Charges	'	'	'	'	'	'	'	'	4,760	5,075	5,622
Income Taxes	'	'	'	'	'	'	'	'	-39,124	-21,849	-19,550
Property Additions	'	'	'	'	'	'	'	'	152,294	108,204	57,369
Identifiable Assets	654,007	'	'	'	608,060	'	'	'	654,007	608,060	'
Operating Segments [Member] | Retail Energy Operations [Member] | Retail Gas and Other Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	107,748	80,486	100,977
Operating Income (Loss)	'	'	'	'	'	'	'	'	278	-1,204	478
Depreciation and Amortization	'	'	'	'	'	'	'	'	93	78	33
Interest Charges	'	'	'	'	'	'	'	'	280	139	186
Income Taxes	'	'	'	'	'	'	'	'	434	-144	511
Property Additions	'	'	'	'	'	'	'	'	702	177	22
Identifiable Assets	50,384	'	'	'	39,481	'	'	'	50,384	39,481	'
Operating Segments [Member] | Retail Energy Operations [Member] | Retail Electric Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	128,932	144,197	206,422
Operating Income (Loss)	'	'	'	'	'	'	'	'	-98	12,683	1,755
Income Taxes	'	'	'	'	'	'	'	'	-40	5,181	717
Identifiable Assets	25,496	'	'	'	21,919	'	'	'	25,496	21,919	'
Operating Segments [Member] | Retail Energy Operations [Member] | On-site Energy Production [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	43,551	38,308	39,919
Operating Income (Loss)	'	'	'	'	'	'	'	'	-2,011	-1,696	2,254
Depreciation and Amortization	'	'	'	'	'	'	'	'	15,192	9,604	4,527
Interest Charges	'	'	'	'	'	'	'	'	4,480	4,936	5,436
Income Taxes	'	'	'	'	'	'	'	'	-40,755	-26,811	-22,258
Property Additions	'	'	'	'	'	'	'	'	151,592	107,993	57,093
Identifiable Assets	576,315	'	'	'	543,416	'	'	'	576,315	543,416	'
Operating Segments [Member] | Retail Energy Operations [Member] | Appliance Service Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	13,723	13,646	17,056
Operating Income (Loss)	'	'	'	'	'	'	'	'	2,995	-225	-1,539
Depreciation and Amortization	'	'	'	'	'	'	'	'	261	308	322
Income Taxes	'	'	'	'	'	'	'	'	1,237	-75	1,480
Property Additions	'	'	'	'	'	'	'	'	0	34	254
Identifiable Assets	1,812	'	'	'	3,244	'	'	'	1,812	3,244	'
Operating Segments [Member] | Corporate and Services [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	31,286	29,318	25,325
Operating Income (Loss)	'	'	'	'	'	'	'	'	370	720	-229
Depreciation and Amortization	'	'	'	'	'	'	'	'	877	699	665
Interest Charges	'	'	'	'	'	'	'	'	6,004	4,219	2,648
Income Taxes	'	'	'	'	'	'	'	'	347	524	254
Property Additions	'	'	'	'	'	'	'	'	3,061	4,308	605
Identifiable Assets	406,245	'	'	'	334,798	'	'	'	406,245	334,798	'
Segment, Discontinued Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Identifiable Assets	1,068	'	'	'	2,290	'	'	'	1,068	2,290	'
Intersegment Elimination [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	'	'	'	'	'	'	'	'	-41,130	-38,978	-41,958
Interest Charges	'	'	'	'	'	'	'	'	-4,906	-2,964	-3,168
Identifiable Assets	($376,773)	'	'	'	($304,525)	'	'	'	($376,773)	($304,525)	'

LEASES_Details

LEASES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Operating Leases, Future Minimum Payments Receivable [Abstract]	'	'
2014	$5,396,000	'
2015	5,396,000	'
2016	5,396,000	'
2017	5,396,000	'
2018	5,396,000	'
Thereafter	45,418,000	'
Total minimum future rentals	72,398,000	'
Thermal Energy Generating Property and Equipment [Member]	'	'
Property Subject to or Available for Operating Lease, Net [Abstract]	'	'
Operating leases expiration date	'May 2027	'
Property and equipment under operating lease	81,800,000	72,300,000
Accumulated depreciation of property and equipment under operating lease	$22,700,000	$20,000,000

RATES_AND_REGULATORY_ACTIONS_D

RATES AND REGULATORY ACTIONS (Details) (USD $)

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

240 Months Ended

1 Months Ended

Sep. 17, 2010

Sep. 30, 2013

Jun. 30, 2013

Feb. 28, 2013

Jul. 31, 2012

Dec. 31, 2013

Oct. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 17, 2010

Sep. 30, 2013

31-May-13

Jun. 30, 2012

Jun. 30, 2011

31-May-13

Jun. 30, 2012

Jun. 30, 2011

31-May-13

Jun. 30, 2012

Jun. 30, 2011

Sep. 17, 2010

Sep. 30, 2013

Oct. 31, 2012

Jan. 31, 2009

31-May-12

Jun. 30, 2011

Mar. 31, 2011

Sep. 30, 2010

Oct. 31, 2011

Oct. 31, 2011

Jan. 31, 2009

Jan. 31, 2009

Sep. 17, 2010

Jan. 31, 2013

Dec. 31, 2011

Mar. 31, 2011

Sep. 30, 2013

Sep. 30, 2012

Jun. 30, 2012

Sep. 30, 2011

Jan. 31, 2014

Jul. 31, 2013

Jun. 30, 2013

31-May-13

Jun. 30, 2012

31-May-12

Jun. 30, 2011

Jan. 31, 2009

Jul. 31, 2013

Jul. 31, 2012

Jul. 31, 2011

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2008

Nov. 30, 2012

Sep. 30, 2013

Jun. 30, 2013

Sep. 30, 2012

Jun. 30, 2012

Oct. 31, 2011

Jun. 30, 2011

customer

Environmental Restoration Costs Expended Net [Member]

Environmental Restoration Costs Expended Net [Member]

Other Regulatory Assets, Deferred Pipeline Integrity Costs [Member]

Other Regulatory Assets, Deferred Pipeline Integrity Costs [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Conservation Incentive Program [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker [Member]

Capital Investment Recovery Tracker, 2009 Spending [Member]

Capital Investment Recovery Tracker, 2010 Spending [Member]

Incremental Revenue [Member]

Basic Gas Supply Service [Member]

Basic Gas Supply Service [Member]

Basic Gas Supply Service [Member]

Basic Gas Supply Service [Member]

Basic Gas Supply Service [Member]

Basic Gas Supply Service [Member]

Basic Gas Supply Service [Member]

Basic Gas Supply Service [Member]

Energy Efficiency Tracker [Member]

Energy Efficiency Tracker [Member]

Energy Efficiency Tracker [Member]

Energy Efficiency Tracker [Member]

Energy Efficiency Tracker [Member]

Energy Efficiency Tracker [Member]

Energy Efficiency Tracker [Member]

Societal Benefits Clause [Member]

Societal Benefits Clause [Member]

Societal Benefits Clause [Member]

Remediation Adjustment Clause [Member]

Remediation Adjustment Clause [Member]

Remediation Adjustment Clause [Member]

Remediation Adjustment Clause [Member]

New Jersey Clean Energy Program [Member]

New Jersey Clean Energy Program [Member]

Universal Service Fund [Member]

Universal Service Fund [Member]

Universal Service Fund [Member]

Universal Service Fund [Member]

Universal Service Fund [Member]

Universal Service Fund [Member]

sites

Non Weather [Member]

Non Weather [Member]

Non Weather [Member]

Weather [Member]

Weather [Member]

Weather [Member]

Capital Expenditures [Member]

Capital Expenditures [Member]

Capital Expenditures [Member]

Capital Expenditures [Member]

Capital Expenditures [Member]

Recovered in 2012 [Member]

Recovered in 2013 [Member]

Capital Expenditures [Member]

Capital Expenditures [Member]

Subsequent Event [Member]

sites

Environmental Restoration Costs Expended Net [Member]

Environmental Restoration Costs Expended Net [Member]

Schedule of Capitalization [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities, Approved Base Rate Increase

$42,100,000

'

'

'

'

'

'

'

'

'

'

'

$16,600,000

'

'

'

'

'

'

'

'

'

'

$6,800,000

'

'

'

'

'

'

'

'

'

'

'

$18,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities, Rate of Return on Base Rate

8.21%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities, Return on Common Equity

10.30%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public Utilities, Annual Depreciation Reduction Attributable To Petition

1,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of Regulatory Costs Not yet Approved

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,700,000

2,300,000

8,400,000

1,300,000

15,500,000

19,600,000

1,400,000

'

'

13,200,000

103,000,000

35,000,000

'

60,300,000

'

40,000,000

50,000,000

70,500,000

32,500,000

'

'

'

'

'

'

27,000,000

'

'

'

'

2,200,000

5,800,000

3,100,000

4,700,000

'

-6,400,000

11,800,000

31,200,000

'

'

'

'

'

'

'

'

'

'

'

'

Amount of Regulatory Costs Not yet Approved, Percent Change in Recoveries

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.80%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of Regulatory Costs Approved

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,800,000

'

2,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

81,300,000

'

'

'

'

'

'

'

'

600,000

27,000,000

'

10,600,000

'

2,100,000

24,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,800,000

'

8,200,000

'

5,400,000

'

Amount of Regulatory Costs Approved, Percent Change in Recoveries

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-0.50%

'

'

'

'

'

'

'

'

'

'

'

8.80%

'

2.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Refunds From Favorable Regulatory Action

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,400,000

18,700,000

21,100,000

'

'

'

'

11,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Costs, Extension Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of Regulatory Costs Not yet Approved, Prior Year Carryover

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28,000,000

2,500,000

'

'

5,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Costs, Original Recovery Period of Expenditures (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Costs, Proposed Recovery Period of Expenditures (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Requested to be Recovered through CIRT, Investments To Be Rolled to Base Rate

'

'

'

'

'

22,500,000

95,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

110,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Requested to be Recovered through CIRT, Revenue Increase

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Requested to be Recovered through CIRT III, Term of AIRP

'

'

'

'4 years

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Requested to be Recovered through CIRT III, Amount of AIRP

'

'

'

141,200,000

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Requested to be Recovered through CIRT III, Annual Amount of AIRP

'

'

'

35,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of Regulatory Costs Available Under Program

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of sites for environmental cleanup (in sites)

'

'

'

'

'

12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12

'

'

'

'

'

'

'

'

'

'

'

Amortization Period of Environmental Remediation Costs (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'7 years

'

'

'

'

'

'

'

'

'

'

'

Amount of Regulatory Costs Approved, Statewide

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,200,000,000

'

54,400,000

'

78,000,000

'

57,400,000

'

Regulatory Costs For Which Reporting Entity is Responsible For

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

41,500,000

7,500,000

'

'

'

'

'

'

Regulatory Costs For Which Reporting Entity is Responsible For, Period of Recovery (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'4 years

'

'

'

'

'

'

'

Regulatory Assets

'

'

'

'

'

296,081,000

'

352,656,000

29,945,000

37,892,000

2,800,000

1,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

29,900,000

37,900,000

'

'

'

'

'

'

'

'

Regulated Costs Recovered

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

92,600,000

'

'

'

'

'

'

'

'

'

'

Amount of Regulatory Costs Not yet Approved, Statewide

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-29,400,000

'

-500,000

'

-9,300,000

Amount of Regulatory Costs Not Yet Approved, Annual Revenue Impact

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-3,700,000

'

-100,000

'

-800,000

Amount of Regulatory Costs Approved, Annual Revenue Impact

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,400,000

'

100,000

'

500,000

'

Regulated Operations, Number of Customers Purchasing Energy Commodities From A Provider Other Then The Reporting Entity (in customers)

'

'

'

'

'

47,074

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Requested to be Recovered through SHARP

'

280,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Requested to be Recovered through SHARP, Term

'

'7 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Costs Requested for Deferral, Storm Related

'

'

$700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

REGULATORY_ASSETS_REGULATORY_L2

REGULATORY ASSETS & REGULATORY LIABILITIES (Details) (USD $)

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2006

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

sites

Environmental Remediation Costs: Expended - Net [Member]

Environmental Remediation Costs: Expended - Net [Member]

Environmental Restoration Costs: Liability for Future Expenditures [Member]

Environmental Restoration Costs: Liability for Future Expenditures [Member]

Deferred Asset Retirement Obligation Costs [Member]

Deferred Asset Retirement Obligation Costs [Member]

Deferred Pension and Other Postretirement Benefit Costs [Member]

Deferred Pension and Other Postretirement Benefit Costs [Member]

Deferred Pension and Other Postretirement Benefit Costs [Member]

Conservation Incentive Program Receivable [Member]

Conservation Incentive Program Receivable [Member]

Societal Benefit Costs Receivable [Member]

Societal Benefit Costs Receivable [Member]

Premium for Early Retirement of debt [Member]

Premium for Early Retirement of debt [Member]

Deferred Interest Rate Contracts [Member]

Deferred Interest Rate Contracts [Member]

Energy Efficiency Tracker [Member]

Energy Efficiency Tracker [Member]

Pipeline Supplier Service Charges [Member]

Pipeline Supplier Service Charges [Member]

Pipeline Integrity Cost [Member]

Pipeline Integrity Cost [Member]

Other Regulatory Assets [Member]

Other Regulatory Assets [Member]

regulatory_assets

Regulatory Assets [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total regulatory assets

$296,081,000

$352,656,000

$29,945,000

$37,892,000

$119,492,000

$107,410,000

$31,142,000

$30,199,000

'

$59,284,000

$95,897,000

$10,526,000

$31,686,000

$10,408,000

$12,801,000

$955,000

$1,075,000

$3,735,000

$7,761,000

$10,420,000

$12,306,000

$7,106,000

$8,771,000

$2,902,000

$1,584,000

$10,166,000

$5,274,000

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)

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of sites where SJG or their predecessors previously operated gas manufacturing plants (in sites)

12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization period deferred costs

'15 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory asset increased

'

'

'

'

'

'

'

'

$37,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

REGULATORY_ASSETS_REGULATORY_L3

REGULATORY ASSETS & REGULATORY LIABILITIES 2 (Details) (USD $)	1 Months Ended
	Sep. 30, 2010	Dec. 31, 2013	Dec. 31, 2012
Regulatory Liabilities [Line Items]	'	'	'
Total regulatory liabilities	'	$60,949,000	$56,517,000
Excess Plant Removal Costs [Member]	'	'	'
Regulatory Liabilities [Line Items]	'	'	'
Total regulatory liabilities	'	40,029,000	45,593,000
Annual amortization reflected in depreciation expense	1,200,000	'	'
Deferred Revenues - Net [Member]	'	'	'
Regulatory Liabilities [Line Items]	'	'	'
Total regulatory liabilities	'	19,067,000	10,924,000
Other Regulatory Liabilities [Member]	'	'	'
Regulatory Liabilities [Line Items]	'	'	'
Total regulatory liabilities	'	$1,853,000	$0

PENSION_AND_OTHER_POSTRETIREME2

PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits [Member]	'	'	'
Net periodic benefit cost [Abstract]	'	'	'
Service Cost	$5,421	$4,533	$3,918
Interest Cost	9,439	9,622	9,524
Expected Return on Plan Assets	-11,914	-10,341	-9,367
Amortizations [Abstract]	'	'	'
Prior Service Cost (Credits)	251	251	267
Actuarial Loss	9,006	7,629	5,440
Net Periodic Benefit Cost	12,203	11,694	9,782
ERIP Costs	0	0	102
Capitalized Benefit Costs	-5,002	-4,684	-3,661
Total Net Periodic Benefit Expense	7,201	7,010	6,223
Other Postretirement Benefits [Member]	'	'	'
Net periodic benefit cost [Abstract]	'	'	'
Service Cost	1,139	1,037	996
Interest Cost	2,730	3,001	3,201
Expected Return on Plan Assets	-2,378	-2,105	-2,248
Amortizations [Abstract]	'	'	'
Prior Service Cost (Credits)	-283	-283	-355
Actuarial Loss	1,738	1,725	1,654
Net Periodic Benefit Cost	2,946	3,375	3,248
Capitalized Benefit Costs	-1,172	-1,340	-1,222
Total Net Periodic Benefit Expense	$1,774	$2,035	$2,026

PENSION_AND_OTHER_POSTRETIREME3

PENSION AND OTHER POSTRETIREMENT BENEFITS 2 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Pension Benefits [Member]	'	'
Regulatory Assets	'	'
Beginning Balance	$68,713	$61,811
Amounts Arising during the Period: Net Actuarial Loss (Gain)	-20,554	11,599
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	-5,319	-4,490
Amounts Amortized to Net Periodic Costs: Prior Service (Cost) Credit	-208	-207
Ending Balance	42,632	68,713
Accumulated Other Comprehensive Loss (pre-tax)	'	'
Beginning Balance	35,431	31,766
Amounts Arising during the Period: Net Actuarial Loss (Gain)	-4,173	6,811
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	-3,642	-3,103
Amounts Amortized to Net Periodic Costs: Prior Service (Cost) Credit	-42	-43
Ending Balance	27,574	35,431
Other Postretirement Benefits [Member]	'	'
Regulatory Assets	'	'
Beginning Balance	27,184	26,435
Amounts Arising during the Period: Net Actuarial Loss (Gain)	-9,171	2,089
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	-1,555	-1,535
Amounts Amortized to Net Periodic Costs: Prior Service (Cost) Credit	194	195
Ending Balance	16,652	27,184
Accumulated Other Comprehensive Loss (pre-tax)	'	'
Beginning Balance	4,195	4,745
Amounts Arising during the Period: Net Actuarial Loss (Gain)	-390	-446
Amounts Amortized to Net Periodic Costs: Net Actuarial Loss	-177	-187
Amounts Amortized to Net Periodic Costs: Prior Service (Cost) Credit	82	83
Ending Balance	$3,710	$4,195

PENSION_AND_OTHER_POSTRETIREME4

PENSION AND OTHER POSTRETIREMENT BENEFITS 3 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Pension Benefits [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Prior Service Costs amortized from Regulatory Assets into net periodic benefit costs	$158
Net Actuarial Loss amortized from Regulatory Assets into net periodic benefit costs	2,856
Prior Service Costs amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs	17
Net Actuarial Loss amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs	2,848
Other Postretirement Benefits [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Prior Service Costs amortized from Regulatory Assets into net periodic benefit costs	133
Net Actuarial Loss amortized from Regulatory Assets into net periodic benefit costs	790
Prior Service Costs amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs	18
Net Actuarial Loss amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs	$182

PENSION_AND_OTHER_POSTRETIREME5

PENSION AND OTHER POSTRETIREMENT BENEFITS 4 (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Amounts Recognized in the Statement of Financial Position Consist of:	'	'	'
Current Liabilities	($1,275,000)	($1,272,000)	'
Noncurrent Liabilities	-57,370,000	-105,168,000	'
Pension Benefits [Member]	'	'	'
Change in Benefit Obligations:	'	'	'
Benefit Obligation at Beginning of Year	224,389,000	194,990,000	'
Service Cost	5,421,000	4,533,000	3,918,000
Interest Cost	9,439,000	9,622,000	9,524,000
Actuarial (Gain) Loss	-14,272,000	23,952,000	'
Retiree Contributions	0	0	'
Benefits Paid	-8,582,000	-8,708,000	'
Benefit Obligation at End of Year	216,395,000	224,389,000	194,990,000
Change in Plan Assets:	'	'	'
Fair Value of Plan Assets at Beginning of Year	150,160,000	116,718,000	'
Actual Return on Plan Assets	22,556,000	15,935,000	'
Employer Contributions	13,959,000	26,215,000	'
Retiree Contributions	0	0	'
Benefits Paid	-8,582,000	-8,708,000	'
Fair Value of Plan Assets at End of Year	178,093,000	150,160,000	116,718,000
Funded Status at End of Year:	-38,302,000	-74,229,000	'
Amounts Recognized in the Statement of Financial Position Consist of:	'	'	'
Current Liabilities	-1,275,000	-1,272,000	'
Noncurrent Liabilities	-37,034,000	-72,796,000	'
Net Amount Recognized at End of Year	-38,309,000	-74,068,000	'
Amounts Recognized in Regulatory Assets Consist of:	'	'	'
Prior Service Costs	634,000	842,000	'
Net Actuarial Loss	41,998,000	67,871,000	'
Amount Recognized in Regulatory Assets	42,632,000	68,713,000	61,811,000
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):	'	'	'
Prior Service Costs (Credit)	69,000	111,000	'
Net Actuarial Loss	27,505,000	35,320,000	'
Amount Recognized in Accumulated Other Comprehensive Loss	27,574,000	35,431,000	31,766,000
Projected benefit obligation	178,800,000	186,400,000	'
Accumulated benefit obligation	163,600,000	168,900,000	'
Pension Benefits [Member] | Amounts Related to Unconsolidated Affiliate [Member]	'	'	'
Change in Plan Assets:	'	'	'
Funded Status at End of Year:	-7,000	161,000	'
Pension Benefits [Member] | Accrued Net Benefit Cost at End of Year [Member]	'	'	'
Change in Plan Assets:	'	'	'
Funded Status at End of Year:	-38,309,000	-74,068,000	'
Other Postretirement Benefits [Member]	'	'	'
Change in Benefit Obligations:	'	'	'
Benefit Obligation at Beginning of Year	68,779,000	64,451,000	'
Service Cost	1,139,000	1,037,000	996,000
Interest Cost	2,730,000	3,001,000	3,201,000
Actuarial (Gain) Loss	-6,361,000	3,861,000	'
Retiree Contributions	388,000	342,000	'
Benefits Paid	-4,320,000	-3,913,000	'
Benefit Obligation at End of Year	62,355,000	68,779,000	64,451,000
Change in Plan Assets:	'	'	'
Fair Value of Plan Assets at Beginning of Year	36,032,000	31,896,000	'
Actual Return on Plan Assets	5,621,000	4,263,000	'
Employer Contributions	3,932,000	3,444,000	'
Retiree Contributions	388,000	342,000	'
Benefits Paid	-4,320,000	-3,913,000	'
Fair Value of Plan Assets at End of Year	41,653,000	36,032,000	31,896,000
Funded Status at End of Year:	-20,701,000	-32,747,000	'
Amounts Recognized in the Statement of Financial Position Consist of:	'	'	'
Current Liabilities	0	0	'
Noncurrent Liabilities	-20,336,000	-32,372,000	'
Net Amount Recognized at End of Year	-20,336,000	-32,372,000	'
Amounts Recognized in Regulatory Assets Consist of:	'	'	'
Prior Service Costs	952,000	758,000	'
Net Actuarial Loss	15,700,000	26,426,000	'
Amount Recognized in Regulatory Assets	16,652,000	27,184,000	26,435,000
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):	'	'	'
Prior Service Costs (Credit)	150,000	68,000	'
Net Actuarial Loss	3,560,000	4,127,000	'
Amount Recognized in Accumulated Other Comprehensive Loss	3,710,000	4,195,000	4,745,000
Other Postretirement Benefits [Member] | Amounts Related to Unconsolidated Affiliate [Member]	'	'	'
Change in Plan Assets:	'	'	'
Funded Status at End of Year:	365,000	375,000	'
Other Postretirement Benefits [Member] | Accrued Net Benefit Cost at End of Year [Member]	'	'	'
Change in Plan Assets:	'	'	'
Funded Status at End of Year:	-20,336,000	-32,372,000	'
Supplemental Employee Retirement Plans, Defined Benefit [Member]	'	'	'
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax):	'	'	'
Projected benefit obligation	37,600,000	38,000,000	'
Accumulated benefit obligation	$36,600,000	$36,300,000	'

PENSION_AND_OTHER_POSTRETIREME6

PENSION AND OTHER POSTRETIREMENT BENEFITS 5 (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits [Member]	'	'	'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'	'
Discount Rate	5.09%	4.26%	'
Rate of Compensation Increase	3.50%	3.25%	'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]	'	'	'
Discount Rate	4.26%	5.03%	5.78%
Expected Long-Term Return on Plan Assets	7.50%	7.50%	8.00%
Rate of Compensation Increase	3.25%	3.25%	3.25%
Other Postretirement Benefits [Member]	'	'	'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'	'
Discount Rate	4.91%	4.14%	'
Rate of Compensation Increase	3.50%	3.25%	'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]	'	'	'
Discount Rate	4.14%	4.92%	5.55%
Expected Long-Term Return on Plan Assets	6.60%	6.60%	7.00%
Rate of Compensation Increase	3.25%	3.25%	3.25%

PENSION_AND_OTHER_POSTRETIREME7

PENSION AND OTHER POSTRETIREMENT BENEFITS 6 (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]	'	'
Medical Care and Drug Cost Trend Rate Assumed for Next Year	7.00%	7.00%
Dental Care Cost Trend Rate Assumed for Next Year	4.75%	4.75%
Rate to which Cost Trend Rates are Assumed to Decline (the Ultimate Trend Rate)	4.75%	4.75%
Year that the Rate Reaches the Ultimate Trend Rate	'2023	'2019

PENSION_AND_OTHER_POSTRETIREME8

PENSION AND OTHER POSTRETIREMENT BENEFITS 7 (Details) (Other Postretirement Benefits [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Other Postretirement Benefits [Member]	'
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	$188
1 - Percentage Point Increase, Effect on Postretirement Benefit Obligation	2,947
1 - Percentage Point Decrease, Effect on the Total of Service and Interest Cost	-149
1 - Percentage Point Decrease, Effect on Postretirement Benefit Obligation	($2,483)

PENSION_AND_OTHER_POSTRETIREME9

PENSION AND OTHER POSTRETIREMENT BENEFITS 8 (Details) (Pension Benefits [Member], USD $)	12 Months Ended
	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Required Capitalization for Plan Asset Allocation	250,000,000
Defined Benefit Plan, Required Capitalization for Plan Asset Allocation, Small Cap	50,000,000
Equity Securities, U.S. Securities [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Minimum	2800.00%
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Maximum	4800.00%
Equity Securities, International Securities [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Minimum	1300.00%
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Maximum	2500.00%
Fixed Income Securities [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Minimum	3200.00%
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Maximum	4200.00%
Other Investments [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Minimum	200.00%
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Maximum	1400.00%

Recovered_Sheet1

PENSION AND OTHER POSTRETIREMENT BENEFITS 9 (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Pension Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Common / Collective Trust Funds [Member]

Common / Collective Trust Funds [Member]

Common / Collective Trust Funds [Member]

Common / Collective Trust Funds [Member]

Common / Collective Trust Funds [Member]

Common / Collective Trust Funds [Member]

Common / Collective Trust Funds [Member]

Common / Collective Trust Funds [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Small-Cap [Member]

U.S. Small-Cap [Member]

U.S. Small-Cap [Member]

U.S. Small-Cap [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Guaranteed Insurance Contract [Member]

Guaranteed Insurance Contract [Member]

Guaranteed Insurance Contract [Member]

Guaranteed Insurance Contract [Member]

Guaranteed Insurance Contract [Member]

Guaranteed Insurance Contract [Member]

Guaranteed Insurance Contract [Member]

Guaranteed Insurance Contract [Member]

Hedge Funds [Member]

Hedge Funds [Member]

Hedge Funds [Member]

Hedge Funds [Member]

Hedge Funds [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Common/Collective Trust Fund - Real Estate [Member]

Common/Collective Trust Fund - Real Estate [Member]

Common/Collective Trust Fund - Real Estate [Member]

Common/Collective Trust Fund - Real Estate [Member]

Common/Collective Trust Fund - Real Estate [Member]

Common/Collective Trust Fund - Real Estate [Member]

Common/Collective Trust Fund - Real Estate [Member]

Common/Collective Trust Fund - Real Estate [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Common/Collective Trust Funds - U.S. [Member]

Mutual Fund - U.S. Large-Cap [Member]

Mutual Fund - U.S. Large-Cap [Member]

Mutual Fund - U.S. Large-Cap [Member]

Mutual Fund - U.S. Large-Cap [Member]

Mutual Fund - U.S. Large-Cap [Member]

Mutual Fund - U.S. Large-Cap [Member]

Mutual Fund - U.S. Large-Cap [Member]

Mutual Fund - U.S. Large-Cap [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Common/Collective Trust Funds - International [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Other Postretirement Benefits [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Equity Securities, U.S. Securities [Member]

Equity Securities, International Securities [Member]

Fixed Income Funds [Member]

Equity Securities, U.S. Securities [Member]

Equity Securities, International Securities [Member]

Fixed Income Funds [Member]

Defined Benefit Plan Disclosure [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Plan Assets

$178,093

$116,718

$19,460

$16,086

$133,370

$112,400

$25,263

$21,674

$416

[1]

$600

[1]

$0

[1]

$0

[1]

$416

[1]

$600

[1]

$0

[1]

$0

[1]

$1,177

[2]

$1,056

[2]

$0

[2]

$0

[2]

$1,177

[2]

$1,056

[2]

$0

[2]

$0

[2]

$51,837

[1]

$42,373

[1]

$0

[1]

$0

[1]

$51,837

[1]

$42,373

[1]

$0

[1]

$0

[1]

$11,661

[3]

$8,963

[3]

$11,661

[3]

$8,963

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$4,135

[3]

$5,275

[3]

$4,135

[3]

$5,275

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$10

[3]

$10

[3]

$0

[3]

$0

[3]

$3,664

[3]

$1,838

[3]

$3,664

[3]

$1,838

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$34,093

[1]

$29,491

[1]

$0

[1]

$0

[1]

$34,093

[1]

$29,491

[1]

$0

[1]

$0

[1]

$45,847

[1]

$38,880

[1]

$0

[1]

$0

[1]

$45,847

[1]

$38,880

[1]

$0

[1]

$0

[1]

$11,322

[4]

$12,449

[4]

$0

[4]

$0

[4]

$0

[4]

$0

[4]

$11,322

[4]

$12,449

[4]

$4,154

[5]

$0

[5]

$0

[5]

$4,154

[5]

$0

$3,046

[6]

$3,216

[6]

$0

[6]

$0

[6]

$0

[6]

$0

[6]

$3,046

[6]

$3,216

[6]

$6,741

[7]

$6,009

[7]

$0

[7]

$0

[7]

$0

[7]

$0

[7]

$6,741

[7]

$6,009

[7]

$41,653

$36,032

$31,896

$2,969

$2,563

$38,684

$33,469

$0

$0

$13,098

[1]

$10,992

[1]

$0

[1]

$0

[1]

$13,098

[1]

$10,992

[1]

$0

[1]

$0

[1]

$2,969

[8]

$2,563

[8]

$2,969

[8]

$2,563

[8]

$0

[8]

$0

[8]

$0

[8]

$0

[8]

$10,586

[1]

$9,340

[1]

$0

[1]

$0

[1]

$10,586

[1]

$9,340

[1]

$0

[1]

$0

[1]

$15,000

[1]

$13,137

[8]

$0

[1]

$0

[8]

$15,000

[1]

$13,137

[8]

$0

[1]

$0

[8]

'

'

'

'

'

'

Fund Valuations Lag Period

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Plan Assets at Beginning of Year

150,160

116,718

19,460

16,086

133,370

112,400

21,674

20,946

416

[1]

600

[1]

0

[1]

0

[1]

416

[1]

600

[1]

0

[1]

0

[1]

1,177

[2]

1,056

[2]

0

[2]

0

[2]

1,177

[2]

1,056

[2]

0

[2]

0

[2]

51,837

[1]

42,373

[1]

0

[1]

0

[1]

51,837

[1]

42,373

[1]

0

[1]

0

[1]

11,661

[3]

8,963

[3]

11,661

[3]

8,963

[3]

0

[3]

0

[3]

0

[3]

0

[3]

4,135

[3]

5,275

[3]

4,135

[3]

5,275

[3]

0

[3]

0

[3]

0

[3]

0

[3]

10

[3]

10

[3]

0

[3]

0

[3]

3,664

[3]

1,838

[3]

3,664

[3]

1,838

[3]

0

[3]

0

[3]

0

[3]

0

[3]

34,093

[1]

29,491

[1]

0

[1]

0

[1]

34,093

[1]

29,491

[1]

0

[1]

0

[1]

45,847

[1]

38,880

[1]

0

[1]

0

[1]

45,847

[1]

38,880

[1]

0

[1]

0

[1]

11,322

[4]

12,449

[4]

0

[4]

0

[4]

0

[4]

0

[4]

12,449

[4]

12,274

4,154

[5]

0

[5]

0

[5]

0

0

3,046

[6]

3,216

[6]

0

[6]

0

[6]

0

[6]

0

[6]

3,216

[6]

3,212

6,741

[7]

6,009

[7]

0

[7]

0

[7]

0

[7]

0

[7]

6,009

[7]

5,460

41,653

36,032

31,896

2,969

2,563

38,684

33,469

0

0

13,098

[1]

10,992

[1]

0

[1]

0

[1]

13,098

[1]

10,992

[1]

0

[1]

0

[1]

2,969

[8]

2,563

[8]

2,969

[8]

2,563

[8]

0

[8]

0

[8]

0

[8]

0

[8]

10,586

[1]

9,340

[1]

0

[1]

0

[1]

10,586

[1]

9,340

[1]

0

[1]

0

[1]

15,000

[1]

13,137

[8]

0

[1]

0

[8]

15,000

[1]

13,137

[8]

0

[1]

0

[8]

'

'

'

'

'

'

Actual return on plan assets [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Relating to assets still held at the reporting date

'

'

'

'

'

'

783

1,578

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-179

1,219

'

'

'

154

0

'

'

'

'

'

'

76

-190

'

'

'

'

'

'

732

549

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Relating to assets sold during the period

'

'

'

'

'

'

448

592

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17

-12

'

'

'

0

0

'

'

'

'

'

'

431

604

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchases, Sales, and Settlements

'

'

'

'

'

'

2,358

-1,442

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-965

-1,032

'

'

'

4,000

0

'

'

'

'

'

'

-677

-410

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Plan Assets at End of Year

$178,093

$116,718

$19,460

$16,086

$133,370

$112,400

$25,263

$21,674

$416

[1]

$600

[1]

$0

[1]

$0

[1]

$416

[1]

$600

[1]

$0

[1]

$0

[1]

$1,177

[2]

$1,056

[2]

$0

[2]

$0

[2]

$1,177

[2]

$1,056

[2]

$0

[2]

$0

[2]

$51,837

[1]

$42,373

[1]

$0

[1]

$0

[1]

$51,837

[1]

$42,373

[1]

$0

[1]

$0

[1]

$11,661

[3]

$8,963

[3]

$11,661

[3]

$8,963

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$4,135

[3]

$5,275

[3]

$4,135

[3]

$5,275

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$10

[3]

$10

[3]

$0

[3]

$0

[3]

$3,664

[3]

$1,838

[3]

$3,664

[3]

$1,838

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$34,093

[1]

$29,491

[1]

$0

[1]

$0

[1]

$34,093

[1]

$29,491

[1]

$0

[1]

$0

[1]

$45,847

[1]

$38,880

[1]

$0

[1]

$0

[1]

$45,847

[1]

$38,880

[1]

$0

[1]

$0

[1]

$11,322

[4]

$12,449

[4]

$0

[4]

$0

[4]

$0

[4]

$0

[4]

$11,322

[4]

$12,449

[4]

$4,154

[5]

$0

[5]

$0

[5]

$4,154

[5]

$0

$3,046

[6]

$3,216

[6]

$0

[6]

$0

[6]

$0

[6]

$0

[6]

$3,046

[6]

$3,216

[6]

$6,741

[7]

$6,009

[7]

$0

[7]

$0

[7]

$0

[7]

$0

[7]

$6,741

[7]

$6,009

[7]

$41,653

$36,032

$31,896

$2,969

$2,563

$38,684

$33,469

$0

$0

$13,098

[1]

$10,992

[1]

$0

[1]

$0

[1]

$13,098

[1]

$10,992

[1]

$0

[1]

$0

[1]

$2,969

[8]

$2,563

[8]

$2,969

[8]

$2,563

[8]

$0

[8]

$0

[8]

$0

[8]

$0

[8]

$10,586

[1]

$9,340

[1]

$0

[1]

$0

[1]

$10,586

[1]

$9,340

[1]

$0

[1]

$0

[1]

$15,000

[1]

$13,137

[8]

$0

[1]

$0

[8]

$15,000

[1]

$13,137

[8]

$0

[1]

$0

[8]

'

'

'

'

'

'

Target plan allocation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

33.00%

20.00%

32.00%

43.00%

30.00%

42.00%

[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 areB 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 fundsB 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,B 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 day lag and, therefore, the value reported herein represents the market value as of September 30, 2013 and 2012, respectively. 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 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.

Recovered_Sheet2

PENSION AND OTHER POSTRETIREMENT BENEFITS 10 (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'
Pension Contributions	$12,700,000	$25,000,000	$0
Pension Benefits [Member]	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'
2014	9,210,000	'	'
2015	9,842,000	'	'
2016	10,289,000	'	'
2017	10,801,000	'	'
2018	12,256,000	'	'
2019- 2023	73,827,000	'	'
Pension Contributions	12,700,000	25,000,000	'
Other Postretirement Benefits [Member]	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'
2014	4,438,000	'	'
2015	4,574,000	'	'
2016	4,660,000	'	'
2017	4,743,000	'	'
2018	4,767,000	'	'
2019- 2023	25,293,000	'	'
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	3,600,000	'	'
Supplemental Employee Retirement Plans, Defined Benefit [Member]	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	$1,300,000	'	'

Recovered_Sheet3

PENSION AND OTHER POSTRETIREMENT BENEFITS 11 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Contribution Plan, Cost Recognized	$1.70	$1.60	$1.50
Employee Qualifying For Defined Benefit Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Contribution Plan, Maximum Annual Contribution Per Employee, Percent	50.00%	'	'
Defined Contribution Plan, Employer Matching Contribution, Percent	6.00%	'	'
Employee Not Qualifying For Defined Benefit Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Contribution Plan, Maximum Annual Contribution Per Employee, Percent	50.00%	'	'
Defined Contribution Plan, Employer Matching Contribution, Percent	8.00%	'	'
Year End Contribution for Employees With Less Then Ten Years of Service	1,000	'	'
Year End Contribution for Employees With More Then Ten Years of Service	1,500	'	'
Years of Service Threshold to Determine Year End Contribution	'10 years	'	'

LINES_OF_CREDIT_Details

LINES OF CREDIT (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Oct. 31, 2013

Minimum [Member]

SJG Commerical Paper Program [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

Revolving Credit Facility [Member]

Uncommitted Bank Lines [Member]

Uncommitted Bank Lines [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Revolving Credit Facility [Member]

Term Line of Credit [Member]

Term Loan Due 2015 [Member]

Term Loan Due 2015 [Member]

Unsecured debt [Member]

Term Loan Due 2015 [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Facility

$610,000,000

'

'

'

$200,000,000

$210,000,000

$200,000,000

$10,000,000

$10,000,000

$400,000,000

'

'

$400,000,000

'

Usage

380,700,000

'

'

'

'

65,500,000

65,500,000

0

'

315,200,000

'

'

315,200,000

'

Available Liquidity

229,300,000

'

'

'

'

144,500,000

134,500,000

10,000,000

'

84,800,000

'

'

84,800,000

'

Expiration Date

'

'

'

'

'

'

'May 2018

'August 2014

'

'

'

'

'February 2018 (A)

[1]

'

Letters of credit outstanding

26,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average borrowing cost

1.04%

1.10%

1.12%

'

'

'

'

'

'

'

'

'

'

'

Average borrowings outstanding during the period

325,600,000

355,300,000

'

'

'

'

'

'

'

'

'

'

'

'

Maximum amounts outstanding during the period

459,000,000

462,200,000

'

'

'

'

'

'

'

'

'

'

'

'

Financial covenant, ratio of indebtedness to consolidated total capitalization minimum

'

'

'

0.65

'

'

'

'

'

'

'

'

'

'

Long-term Debt

$701,400,000

[2]

$626,400,000

[2]

'

'

'

'

'

'

'

'

$50,000,000

[2],[3]

$0

[2],[3]

'

$50,000,000

Fixed maturities of notes, at maximum number of days

'

'

'

'

'270 days

'

'

'

'

'

'

'

'

'

[1]

Includes letters of credit outstanding in the amount of $26.8 million.

[2]

Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000.

[3]

In October 2013, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2015. This agreement replaces existing facilities that were set to expire in November 2013. The variable rate at December 31, 2013 was 1.22%. These notes have been reclassified from Notes Payable-Banks to Long-Term Debt on the consolidated balances sheets, but are not included in the consolidated statement of cash flows as the reclassification is considered a non-cash financing activity.

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Nov. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Nov. 30, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Jul. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2012

Oct. 31, 2013

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

South Jersey Gas Company [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

South Jersey Industries Inc [Member]

Line of Credit [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

First Mortgage Bonds [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Medium-term Notes [Member]

Medium-term Notes [Member]

Medium-term Notes [Member]

Medium-term Notes [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Unsecured debt [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

South Jersey Industries Inc [Member]

Series Due 2013, 4.46% [Member]

Series Due 2013, 4.46% [Member]

Series Due 2013, 5.027% [Member]

Series Due 2013, 5.027% [Member]

Series Due 2014, 4.52% [Member]

Series Due 2014, 4.52% [Member]

Series Due 2014, 5.115% [Member]

Series Due 2014, 5.115% [Member]

Series Due 2015, 5.387% [Member]

Series Due 2015, 5.387% [Member]

Series Due 2016, 5.437% [Member]

Series Due 2016, 5.437% [Member]

Series Due 2016, 4.6% [Member]

Series Due 2016, 4.6% [Member]

Series Due 2017, 4.657% [Member]

Series Due 2017, 4.657% [Member]

Series Due 2018, 7.97% [Member]

Series Due 2018, 7.97% [Member]

Series Due 2018, 7.125% [Member]

Series Due 2018, 7.125% [Member]

Series Due 2019, 5.587% [Member]

Series Due 2019, 5.587% [Member]

Series Due 2024, 3.00% [Member]

Series Due 2024, 3.00% [Member]

Series Due 2024, 3.00% [Member]

Series Due 2024, 3.03% [Member]

Series Due 2024, 3.03% [Member]

Series Due 2024, 3.03% [Member]

Series Due 2025, 3.63% [Member]

Series Due 2025, 3.63% [Member]

Series Due 2026, 4.84% [Member]

Series Due 2026, 4.84% [Member]

Series Due 2026, 4.93% [Member]

Series Due 2026, 4.93% [Member]

Series Due 2027, 4.03% [Member]

Series Due 2027, 4.03% [Member]

Series Due 2030, 4.01% [Member]

Series Due 2030, 4.01% [Member]

Series Due 2030, 4.01% [Member]

Series Due 2032, 3.74% [Member]

Series Due 2032, 3.74% [Member]

Series Due 2033, 5.55% [Member]

Series Due 2033, 5.55% [Member]

Series Due 2034, 6.213% [Member]

Series Due 2034, 6.213% [Member]

Series Due 2035, 5.45% [Member]

Series Due 2035, 5.45% [Member]

Series A. 2006 Bonds [Member]

Series A. 2006 Bonds [Member]

Series Due 2013, 4.46% [Member]

Series Due 2013, 5.027% [Member]

Series A. 2031 Bonds [Member]

Series A. 2031 Bonds [Member]

Series B. 2021 Bonds [Member]

Series B. 2021 Bonds [Member]

Series A. 2036 [Member]

Series A. 2036 [Member]

Term Loan Due 2015 [Member]

Term Loan Due 2015 [Member]

Series A Notes Due 2015, 2.39% [Member]

Series A Notes Due 2015, 2.39% [Member]

Series A Notes Due 2015, 2.39% [Member]

Series B Notes Due 2017, 2.71% [Member]

Series B Notes Due 2017, 2.71% [Member]

Series B Notes Due 2017, 2.71% [Member]

Series C Notes Due 2022, 3.46% [Member]

Series C Notes Due 2022, 3.46% [Member]

Series C Notes Due 2022, 3.46% [Member]

Unsecured debt [Member]

Term Loan Due 2015 [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

4.46%

'

5.03%

'

4.52%

'

5.12%

'

5.39%

'

5.44%

'

4.60%

'

4.66%

'

7.97%

'

7.13%

'

5.59%

'

3.00%

'

3.00%

3.03%

'

3.03%

3.63%

'

4.84%

'

4.93%

'

4.03%

'

4.01%

4.01%

'

3.74%

'

5.55%

'

6.21%

'

5.45%

'

'

'

'

'

4.46%

5.03%

'

'

'

'

'

'

'

'

'

'

'

'

2.39%

'

'

2.71%

'

'

3.46%

'

Long-Term Debt

$701,400,000

[1]

$626,400,000

[1]

$0

[1],[2],[3]

$10,500,000

[1],[2],[3]

$0

[1],[2],[3]

$14,500,000

[1],[2],[3]

$11,000,000

[1],[2]

$11,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$17,000,000

[1],[2]

$17,000,000

[1],[2]

$15,000,000

[1],[2]

$15,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$20,000,000

[1],[2]

$20,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$50,000,000

[1],[2],[4]

$50,000,000

[1],[2],[4]

$50,000,000

[1],[2],[4]

$35,000,000

[1],[2],[4]

$35,000,000

[1],[2],[4]

$35,000,000

[1],[2],[4]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$15,000,000

[1],[2]

$15,000,000

[1],[2]

$45,000,000

[1],[2]

$45,000,000

[1],[2]

$45,000,000

[1],[2]

$45,000,000

[1],[2]

$50,000,000

[1],[2],[5]

$50,000,000

[1],[2],[5]

$0

[1],[2],[5]

$35,000,000

[1],[2]

$35,000,000

[1],[2]

$32,000,000

[1],[2]

$32,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$10,000,000

[1],[2]

$25,000,000

[1],[6]

$25,000,000

[1],[6]

'

'

'

'

$61,400,000

$20,000,000

[1],[7]

$20,000,000

[1],[7]

$25,000,000

[1],[7]

$25,000,000

[1],[7]

$16,400,000

[1],[7]

$16,400,000

[1],[7]

$50,000,000

[1],[8]

$0

[1],[8]

'

$64,000,000

[1],[9]

$64,000,000

[1],[9]

$64,000,000

[1],[9]

$16,000,000

[1],[9]

$16,000,000

[1],[9]

$16,000,000

[1],[9]

$35,000,000

[1],[9]

$35,000,000

[1],[9]

$35,000,000

[1],[9]

$50,000,000

Less Current Maturities

-21,000,000

[1]

-25,000,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Long-Term Debt

680,400,000

[1]

601,400,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Fiscal Year Maturity [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2014

21,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2015

74,909,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2016

27,909,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2017

31,909,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2018

28,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Extinguishment of Debt, Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,500,000

14,500,000

[1],[2],[3]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate at Period End

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.07%

'

'

'

'

'

'

0.08%

'

0.18%

'

0.08%

'

'

'

'

'

'

'

'

'

'

'

'

'

1.22%

Long Term Debt, Outstanding Amount Not Fixed By Interest Rate Derivatives

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Fixed Interest Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.41%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

115,000,000

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Maximum Borrowing Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Unused Borrowing Capacity, Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$30,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000.

[2]

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.

[3]

In July 2013, SJG called its $10.5 million, 4.46% MTN due July 2013 and $14.5 million, 5.027% MTN due September 2013.

[4]

In September 2012, SJG issued $50.0 million of 3.00% aggregate principal amount of MTN's due September 2024. In November 2012, SJG issued $35.0 million of 3.03% aggregate principal amount of MTN's due November 2024.

[5]

In November 2013, SJG issued $50.0 million of 4.01% aggregate principal amount of its MTN's due November 2030.

[6]

These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of DecemberB 31, 2013 was 0.07%. Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August, 2015. These bonds contain no financial covenants.

[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 DecemberB 31, 2013 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.08%, 0.18% and 0.08% respectively. The interest rate on all but $27.1 million of the bonds has been effectively fixed via interest rate swaps at 4.41% 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 August, 2015.

[8]

In October 2013, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2015. This agreement replaces existing facilities that were set to expire in November 2013. The variable rate at December 31, 2013 was 1.22%. These notes have been reclassified from Notes Payable-Banks to Long-Term Debt on the consolidated balances sheets, but are not included in the consolidated statement of cash flows as the reclassification is considered a non-cash financing activity.

[9]

In June 2012, the Company issued $115.0 million aggregate principal amount of long-term debt, consisting of the following: (a) $64.0 million aggregate principal amount of 2.39% Senior Notes due June 2015; (b) $16.0 million aggregate principal amount of 2.71% Senior Notes due June 2017; and (c) $35.0 million aggregate principal amount of 3.46% Senior Notes due June 2022.

COMMITMENTS_AND_CONTINGENCIES_1

COMMITMENTS AND CONTINGENCIES (Details) (USD $)

12 Months Ended

408 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Feb. 28, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 30, 2007

Dec. 31, 2013

Dec. 31, 2013

31-May-12

31-May-12

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

sites

sites

ACR Energy Partners LLC [Member]

ACR Energy Partners LLC [Member]

Letter of Credit, Developer [Member]

Standby Letter of Credit [Member]

Standby Letter of Credit, Variable-rate Demand Bonds [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

Environmental Restoration Costs [Member]

LVE Energy Partners [Member]

LVE Energy Partners [Member]

Energenic [Member]

Energenic [Member]

Energenic [Member]

Parental Guarantee [Member]

South Jersey Resources Group, Llc [Member]

South Jersey Gas Company [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

unions

unions

Fuel Oil [Member]

Sites Comprising the Majority the Environmental Remediation [Member]

UMM Energy Partners, LLC [Member]

UMM Energy Partners, LLC [Member]

LVE Energy Partners, LLC (LVE) [Member]

LVE Energy Partners [Member]

sites

sites

Maximum [Member]

LVE Energy Partners, LLC (LVE) [Member]

Commitment and Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Contract for Purchase of Electric Power, Monthly Fees Paid to Supplier

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$400,000

$4,000,000

'

'

Long-term Contract for Purchase of Electric Power, Plant Output Being Purchased, Minimum (in dts/d)

545,500

'

545,500

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Contract for Purchase of Electric Power, Plant Output Being Purchased, Maximum (in dts/d)

810,000

'

810,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Contract for Purchase of Electric Power, Contract Term, Minimum (in years)

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Contract for Purchase of Electric Power, Contract Term, Maximum (in years)

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrual for pending litigation

3,000,000

3,100,000

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Collective bargaining agreements [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of personnel represented by collective bargaining agreements (in hundredths)

45.00%

'

45.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of unions

2

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Guarantees [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Guarantor Obligations, Current Carrying Value

114,400,000

'

114,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability recorded related to guarantees

700,000

'

700,000

'

'

'

'

'

'

'

'

'

800,000

500,000

'

'

'

'

'

'

'

Equity interest

'

'

'

'

50.00%

'

'

'

'

'

'

50.00%

'

50.00%

'

'

'

'

'

50.00%

'

Contract with a resort developer (in years)

'

'

'

'20 years

'

'

'

'

'

'

'

'25 years

'

'

'

'

'

'

'

'

'

Outstanding balance of bank debt

680,400,000

[1]

601,400,000

[1]

680,400,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letter of credit provided

610,000,000

'

610,000,000

'

'

5,000,000

26,800,000

87,600,000

'

'

'

'

'

'

'

'

'

'

210,000,000

'

'

Proceeds from Divestiture of Interest in Joint Venture

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

57,900,000

Notes Receivable

7,882,000

0

7,882,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notes receivable - affiliate

8,908,000

39,495,000

8,908,000

'

'

'

'

'

'

'

'

'

9,700,000

'

'

'

'

'

'

'

'

Interest and other project related costs

3,200,000

'

3,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Guaranteed amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,800,000

'

'

'

'

Maximum amount of obligation under guarantee contracts

4,200,000

'

4,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital contribution obligation [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contract Term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 years

'

'

'

'

'

'

Annual Obligations Under the Agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,200,000

'

'

'

'

'

Environmental remediation costs [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of sites for environmental cleanup (in number of sites)

12

'

12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Site Contingency, Number of Sites Covered By Insurance

11

'

11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Site Contingency, Insurance Policy Limit

50,000,000

'

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrual for Environmental Loss Contingencies [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance, Beginning of Year

112,098,000

94,160,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accruals

22,821,000

30,349,000

342,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expenditures

-11,490,000

-12,411,000

-219,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance, End of Year

123,429,000

112,098,000

123,429,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Range of Possible Loss, Minimum

'

'

'

'

'

'

'

'

119,500,000

900,000

100,400,000

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Range of Possible Loss, Maximum

'

'

'

'

'

'

'

'

223,500,000

1,800,000

192,800,000

'

'

'

'

'

'

'

'

'

'

Number of Sites Affected By Environmental Remediation

'

'

'

'

'

'

'

'

'

6

6

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Range of Possible Loss, Minimum, Assumed By Another Entity

'

'

'

'

'

'

'

'

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Range of Possible Loss, Maximum, Assumed By Another Entity

'

'

'

'

'

'

'

'

$5,500,000

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000.

DERIVATIVE_INSTRUMENTS_Details

DERIVATIVE INSTRUMENTS (Details) (USD $)	Dec. 31, 2013
Marina Energy LLC [Member] | Interest Rate Swap, 3,900,000 [Member]	'
Derivative [Line Items]	'
Notional Amount	$3,900,000
Fixed Interest Rate	4.80%
Marina Energy LLC [Member] | Interest Rate Swap, 8,000,000 [Member]	'
Derivative [Line Items]	'
Notional Amount	8,000,000
Fixed Interest Rate	4.78%
Marina Energy LLC [Member] | Interest Rate Swap, 14,500,000 [Member]	'
Derivative [Line Items]	'
Notional Amount	14,500,000
Fixed Interest Rate	3.91%
Marina Energy LLC [Member] | Interest Rate Swap, 500,000 [Member]	'
Derivative [Line Items]	'
Notional Amount	500,000
Fixed Interest Rate	3.91%
Marina Energy LLC [Member] | Interest Rate Swap, 330,000 [Member]	'
Derivative [Line Items]	'
Notional Amount	330,000
Fixed Interest Rate	3.91%
Marina Energy LLC [Member] | Interest Rate Swap, 7,100,000 [Member]	'
Derivative [Line Items]	'
Notional Amount	7,100,000
Fixed Interest Rate	4.90%
South Jersey Gas Company [Member] | Interest Rate Swap, 12,500,000 Contract 1 [Member]	'
Derivative [Line Items]	'
Notional Amount	12,500,000
Fixed Interest Rate	3.43%
South Jersey Gas Company [Member] | Interest Rate Swap, 12,500,000 Contract 2 [Member]	'
Derivative [Line Items]	'
Notional Amount	$12,500,000
Fixed Interest Rate	3.43%
Basis and Index Related Purchase and Sales Contracts [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	21.8
Natural Gas (in MMdts) [Member] | Derivative Transaction Type, Purchase [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	17.9
Natural Gas (in MMdts) [Member] | Derivative Transaction Type, Sale [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	19.1
Electricity (in MMmwh) [Member] | Derivative Transaction Type, Purchase [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	1,300,000
Electricity (in MMmwh) [Member] | Derivative Transaction Type, Sale [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	1,300,000

DERIVATIVE_INSTRUMENTS_2_Detai

DERIVATIVE INSTRUMENTS 2 (Details) (Not Designated as Hedging Instrument [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	$82,778	$36,539
Fair value Derivative Liabilities	106,800	42,693
Commodity Contract [Member] | Derivatives-Energy Related-Current [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	56,327	24,242
Fair value Derivative Liabilities	77,993	23,828
Commodity Contract [Member] | Derivatives-Energy Related-NonCurrent [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	26,451	12,297
Fair value Derivative Liabilities	22,131	5,403
Interest Rate Contract [Member] | Derivatives-Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$6,676	$13,462

DERIVATIVE_INSTRUMENTS_3_Detai

DERIVATIVE INSTRUMENTS 3 (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives - Energy Related [Member]	'		'
Offsetting Derivative Assets [Abstract]	'		'
Gross amounts of recognized assets/liabilities	$82,778		$36,539
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	82,778		36,539
Gross amounts not offset in the balance sheet, Financial Instruments	-28,082	[1]	-12,975	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	-498		0
Net amount	54,198		23,564
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-100,124		-29,231
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-100,124		-29,231
Gross amounts not offset in the balance sheet, Financial Instruments	28,082	[2]	12,975	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	29,639		6,347
Net amount	-42,403		-9,909
Derivatives - Other [Member]	'		'
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-6,676		-13,462
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-6,676		-13,462
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	($6,676)		($13,462)
[1]	The balances at DecemberB 31, 2013 and 2012 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at DecemberB 31, 2013 and 2012 were related to derivative assets which can be net settled against derivative liabilities.

DERIVATIVE_INSTRUMENTS_4_Detai

DERIVATIVE INSTRUMENTS 4 (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Interest Rate Contracts [Abstract]	'		'		'
(Losses) gains recognized in AOCI on effective portion	$0		($752,000)		($2,773,000)
(Losses) gains reclassified from AOCI into income	-448,000	[1]	-594,000	[1]	-1,435,000	[1]
Losses recognized in income on ineffective portion	0	[1]	0	[1]	0	[1]
(Losses) gains on energy related commodity contracts	-25,823,000	[2]	-193,000	[2]	5,377,000	[2]
Gains (losses) on interest rate contracts	2,760,000	[1]	660,000	[1]	-149,000	[1]
Derivative instruments not designated as hedging instruments, gain (loss), net	-23,063,000		467,000		5,228,000
Realized losses on derivative instruments on energy-related contracts	400,000		15,400,000		12,900,000
Fair value derivative instruments with credit-risk-related features	38,700,000		'		'
Additional collateral, aggregate fair value	$29,800,000		'		'
[1]	Included in Interest Charges
[2]	Included in Operating Revenues - Non Utility

FAIR_VALUE_OF_FINANCIAL_ASSETS2

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012
Changes in significant unobservable inputs [Roll forward]	'		'
Balance at beginning of period	$2,762,000		($5,958,000)
Other changes in fair value from continuing and new contracts, net	1,573,000		2,902,000
Transfers in and/or out of Level 3, net	2,748,000		'
Settlements	1,012,000		5,818,000
Balance at end of period	8,095,000		2,762,000
Gain included in earnings from change in unrealized losses relating to assets and liabilities held at period end	5,300,000		'
Level 3 [Member] | Forward Contracts [Member] | Natural Gas (in MMdts) [Member]	'		'
Liabilities [Abstract]	'		'
Assets	41,444,000		4,340,000
Liabilities	36,043,000		4,986,000
Level 3 [Member] | Forward Contracts [Member] | Natural Gas (in MMdts) [Member] | Minimum [Member]	'		'
Liabilities [Abstract]	'		'
Forward price (in dollars per dt)	-1.75		-0.35
Level 3 [Member] | Forward Contracts [Member] | Natural Gas (in MMdts) [Member] | Maximum [Member]	'		'
Liabilities [Abstract]	'		'
Forward price (in dollars per dt)	6.05		2.92
Level 3 [Member] | Forward Contracts [Member] | Natural Gas (in MMdts) [Member] | Weighted Average [Member]	'		'
Liabilities [Abstract]	'		'
Forward price (in dollars per dt)	-0.79		-0.12
Level 3 [Member] | Forward Contracts [Member] | Electricity (in MMmwh) [Member]	'		'
Liabilities [Abstract]	'		'
Assets	9,767,000		6,590,000
Liabilities	7,073,000		3,182,000
Level 3 [Member] | Forward Contracts [Member] | Electricity (in MMmwh) [Member] | Minimum [Member] | On-Peak [Member]	'		'
Liabilities [Abstract]	'		'
Fixed electric load profile	8.06%		21.62%
Level 3 [Member] | Forward Contracts [Member] | Electricity (in MMmwh) [Member] | Minimum [Member] | Off-Peak [Member]	'		'
Liabilities [Abstract]	'		'
Fixed electric load profile	0.00%		0.00%
Level 3 [Member] | Forward Contracts [Member] | Electricity (in MMmwh) [Member] | Maximum [Member] | On-Peak [Member]	'		'
Liabilities [Abstract]	'		'
Fixed electric load profile	100.00%		100.00%
Level 3 [Member] | Forward Contracts [Member] | Electricity (in MMmwh) [Member] | Maximum [Member] | Off-Peak [Member]	'		'
Liabilities [Abstract]	'		'
Fixed electric load profile	91.94%		78.38%
Level 3 [Member] | Forward Contracts [Member] | Electricity (in MMmwh) [Member] | Weighted Average [Member] | On-Peak [Member]	'		'
Liabilities [Abstract]	'		'
Fixed electric load profile	54.55%		53.64%
Level 3 [Member] | Forward Contracts [Member] | Electricity (in MMmwh) [Member] | Weighted Average [Member] | Off-Peak [Member]	'		'
Liabilities [Abstract]	'		'
Fixed electric load profile	45.45%		46.36%
Fair Value, Measurements, Recurring [Member] | Total [Member]	'		'
Assets [Abstract]	'		'
Available-for-Sale Securities	8,716,000	[1]	7,538,000	[1]
Derivatives - Energy Related Assets	82,778,000	[2]	36,539,000	[2]
Total Assets	91,494,000		44,077,000
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	100,124,000	[2]	29,231,000	[2]
Derivatives - Other	6,676,000	[3]	13,462,000	[3]
Total Liabilities	106,800,000		42,693,000
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'		'
Assets [Abstract]	'		'
Available-for-Sale Securities	8,716,000	[1]	787,000	[1]
Derivatives - Energy Related Assets	4,385,000	[2]	9,404,000	[2]
Total Assets	13,101,000		10,191,000
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	4,236,000	[2]	5,399,000	[2]
Derivatives - Other	0	[3]	0	[3]
Total Liabilities	4,236,000		5,399,000
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'		'
Assets [Abstract]	'		'
Available-for-Sale Securities	0	[1]	6,751,000	[1]
Derivatives - Energy Related Assets	27,182,000	[2]	16,205,000	[2]
Total Assets	27,182,000		22,956,000
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	52,772,000	[2]	15,664,000	[2]
Derivatives - Other	6,676,000	[3]	13,462,000	[3]
Total Liabilities	59,448,000		29,126,000
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'		'
Assets [Abstract]	'		'
Available-for-Sale Securities	0	[1]	0	[1]
Derivatives - Energy Related Assets	51,211,000	[2]	10,930,000	[2]
Total Assets	51,211,000		10,930,000
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	43,116,000	[2]	8,168,000	[2]
Derivatives - Other	0	[3]	0	[3]
Total Liabilities	$43,116,000		$8,168,000
[1]	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.
[2]	Derivatives b 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.
[3]	Derivatives b 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_COMPREHENSIV2

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Balance at January 1	($31,105)	[1]	'		'
Other comprehensive income before reclassifications	3,291		'		'
Amounts reclassified from AOCL	7,054	[2]	'		'
Other Comprehensive Income (Loss) - Net of Tax	10,345	[1]	-2,667	[1]	-6,626	[1]
Balance at December 31	-20,760	[1]	-31,105	[1]	'
Combined statutory tax rate	41.00%		'		'
Postretirement Liability Adjustment [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Balance at January 1	-23,437	[1]	-21,595	[1]	-15,928	[1]
Other comprehensive income before reclassifications	2,699		'		'
Amounts reclassified from AOCL	2,235	[2]	'		'
Other Comprehensive Income (Loss) - Net of Tax	4,934	[1]	-1,842	[1]	-5,667	[1]
Balance at December 31	-18,503	[1]	-23,437	[1]	-21,595	[1]
Unrealized Gain (Loss) on Derivatives-Other [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Balance at January 1	-2,962	[1]	-2,870	[1]	-2,082	[1]
Other comprehensive income before reclassifications	'		'		'
Amounts reclassified from AOCL	265	[2]	'		'
Other Comprehensive Income (Loss) - Net of Tax	265	[1]	-92	[1]	-788	[1]
Balance at December 31	-2,697	[1]	-2,962	[1]	-2,870	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Balance at January 1	294	[1]	-206	[1]	154	[1]
Other comprehensive income before reclassifications	592		'		'
Amounts reclassified from AOCL	-489	[2]	'		'
Other Comprehensive Income (Loss) - Net of Tax	103	[1]	500	[1]	-360	[1]
Balance at December 31	397	[1]	294	[1]	-206	[1]
Other Comprehensive Income (Loss) of Affiliated Companies [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Balance at January 1	-5,000	[1]	'		'
Other comprehensive income before reclassifications	'		'		'
Amounts reclassified from AOCL	5,043	[2]	'		'
Other Comprehensive Income (Loss) - Net of Tax	5,043		'		'
Balance at December 31	$43	[1]	'		'
[1]	Determined using a combined statutory tax rate of 41%.
[2]	See table below.

ACCUMULATED_OTHER_COMPREHENSIV3

ACCUMULATED OTHER COMPREHENSIVE LOSS 2 (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operations

'

'

'

'

'

'

'

'

$120,205

$113,643

$100,901

Interest Charges

'

'

'

'

'

'

'

'

18,825

18,986

24,078

Other Income

'

'

'

'

'

'

'

'

-10,979

-11,104

-15,642

Equity in Loss of Affiliated Companies

'

'

'

'

'

'

'

'

-1,585

-2,239

810

Income Tax Benefit (Expense)

-9,621

-5,533

-11,632

7,772

-757

-2,576

-1,072

15,884

-19,440

10,850

22,200

Income from Continuing Operations

-39,357

1,221

-916

-43,337

-25,569

-2,164

-10,832

-54,211

-82,389

-92,776

-89,859

Reclassification out of Accumulated Other Comprehensive Income [Member]

'

'

'

'

'

'

'

'

'

'

'

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Income from Continuing Operations

'

'

'

'

'

'

'

'

7,054

'

'

Reclassification out of Accumulated Other Comprehensive Income [Member] | Postretirement Liability Adjustment [Member]

'

'

'

'

'

'

'

'

'

'

'

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operations

'

'

'

'

'

'

'

'

3,779

'

'

Income Tax Benefit (Expense)

'

'

'

'

'

'

'

'

-1,544

[1]

'

'

Income from Continuing Operations

'

'

'

'

'

'

'

'

2,235

'

'

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

'

'

'

'

'

'

'

'

448

'

'

Income Tax Benefit (Expense)

'

'

'

'

'

'

'

'

-183

[1]

'

'

Income from Continuing Operations

'

'

'

'

'

'

'

'

265

'

'

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

'

'

'

'

'

'

'

'

-828

'

'

Income Tax Benefit (Expense)

'

'

'

'

'

'

'

'

339

[1]

'

'

Income from Continuing Operations

'

'

'

'

'

'

'

'

-489

'

'

Reclassification out of Accumulated Other Comprehensive Income [Member] | Other Comprehensive Income (Loss) of Affiliated Companies [Member]

'

'

'

'

'

'

'

'

'

'

'

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Equity in Loss of Affiliated Companies

'

'

'

'

'

'

'

'

8,515

'

'

Income Tax Benefit (Expense)

'

'

'

'

'

'

'

'

-3,472

[1]

'

'

Income from Continuing Operations

'

'

'

'

'

'

'

'

$5,043

'

'

[1]

Determined using a combined statutory tax rate of 41%.

SUBSEQUENT_EVENTS_Details

SUBSEQUENT EVENTS (Details) (USD $)	1 Months Ended				1 Months Ended
	Feb. 28, 2013	Oct. 31, 2013	Jul. 31, 2012	Jan. 31, 2014	Oct. 31, 2013
		South Jersey Gas Company [Member]	South Jersey Gas Company [Member]	South Jersey Gas Company [Member]	Maximum [Member]
				Subsequent Event [Member]	Subsequent Event [Member]
				Mortgages [Member]
Subsequent Event [Line Items]	'	'	'	'	'
Debt Instrument, Face Amount	'	'	'	$30,000,000	'
Investment Requested to be Recovered through CIRT III, Annual Amount of AIRP	35,300,000	'	0.0423	'	'
Amount of Additional Debt Petitioned For	'	'	'	'	$200,000,000
Amount of Additional Debt Petitioned For, Period	'	'3 years	'	'	'

Quarterly_Financial_Data_Unaud2

Quarterly Financial Data (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Information Disclosure [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	$224,390	$128,808	$122,592	$255,631	$197,558	$111,977	$121,913	$274,832	$731,421	$706,280	$828,560
Expenses:	'	'	'	'	'	'	'	'	'	'	'
Cost of Sales - (Excluding depreciation)	139,703	89,160	87,827	152,301	120,866	70,549	69,519	156,868	'	'	'
Operations and Maintenance Including Fixed Charges	54,674	47,789	47,114	52,226	50,072	45,970	45,467	46,071	'	'	'
Income Taxes	-9,621	-5,533	-11,632	7,772	-757	-2,576	-1,072	15,884	-19,440	10,850	22,200
Energy and Other Taxes	2,861	1,458	1,664	3,833	2,749	1,494	1,865	3,878	9,816	9,986	12,189
Total Expenses	187,617	132,874	124,973	216,132	172,930	115,437	115,779	222,701	'	'	'
Other Income and Expense	2,584	2,845	3,297	3,838	941	5,624	4,698	2,080	'	'	'
Income from Continuing Operations	39,357	-1,221	916	43,337	25,569	2,164	10,832	54,211	82,389	92,776	89,859
(Loss) Income from Discontinued Operations - (Net of tax benefit)	-97	-200	-28	-471	-383	-151	-498	-136	-796	-1,168	-568
Net Income (Loss)	$39,260	($1,421)	$888	$42,866	$25,186	$2,013	$10,334	$54,075	'	'	'
Basic Earnings Per Common Share:	'	'	'	'	'	'	'	'	'	'	'
Continuing Operations (in dollars per share)	$1.22	($0.04)	$0.03	$1.37	$0.81	$0.07	$0.36	$1.79	$2.58	$3.02	$3
Discontinued Operations (in dollars per share)	$0	$0	$0	($0.02)	($0.01)	($0.01)	($0.02)	$0	($0.03)	($0.04)	($0.02)
Basic Earnings Per Common Share (in dollars per share)	$1.22	($0.04)	$0.03	$1.35	$0.80	$0.07	$0.34	$1.79	$2.55	$2.98	$2.98
Average Shares of Common Stock Outstanding - Basic (in shares)	32,259	31,984	31,949	31,757	31,465	30,861	30,393	30,249	31,989	30,744	30,000
Diluted Earnings Per Common Share:	'	'	'	'	'	'	'	'	'	'	'
Continuing Operations (in dollars per share)	$1.22	($0.04)	$0.03	$1.36	$0.81	$0.07	$0.36	$1.79	$2.57	$3.01	$2.99
Discontinued Operations (in dollars per share)	$0	$0	$0	($0.01)	($0.01)	($0.01)	($0.02)	($0.01)	($0.02)	($0.04)	($0.02)
Diluted Earnings Per Common Share (in dollars per share)	$1.22	($0.04)	$0.03	$1.35	$0.80	$0.07	$0.34	$1.78	$2.55	$2.97	$2.97
Average Shares of Common Stock Outstanding - Diluted (in shares)	32,306	31,984	32,012	31,811	31,547	30,945	30,472	30,323	32,046	30,824	30,086

Schedule_I_Details

Schedule I (Details) (USD $)

3 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Operating Expenses:

'

'

'

'

'

'

'

'

'

'

'

'

Operations

'

'

'

'

'

'

'

'

$120,205,000

$113,643,000

$100,901,000

'

Depreciation

'

'

'

'

'

'

'

'

49,637,000

41,336,000

35,749,000

'

Energy and Other Taxes

2,861,000

1,458,000

1,664,000

3,833,000

2,749,000

1,494,000

1,865,000

3,878,000

9,816,000

9,986,000

12,189,000

'

Operating Income

'

'

'

'

'

'

'

'

69,636,000

109,898,000

121,607,000

'

Other Income:

'

'

'

'

'

'

'

'

'

'

'

'

Equity in Earnings of Subsidiaries

'

'

'

'

'

'

'

'

1,585,000

2,239,000

-810,000

'

Total Other Income

'

'

'

'

'

'

'

'

10,979,000

11,104,000

15,642,000

'

Interest Charges

'

'

'

'

'

'

'

'

18,825,000

18,986,000

24,078,000

'

Income Taxes

-9,621,000

-5,533,000

-11,632,000

7,772,000

-757,000

-2,576,000

-1,072,000

15,884,000

-19,440,000

10,850,000

22,200,000

'

Income from Continuing Operations

39,357,000

-1,221,000

916,000

43,337,000

25,569,000

2,164,000

10,832,000

54,211,000

82,389,000

92,776,000

89,859,000

'

Equity in Undistributed Earnings of Discontinued Subsidiaries

-97,000

-200,000

-28,000

-471,000

-383,000

-151,000

-498,000

-136,000

-796,000

-1,168,000

-568,000

'

Net Income

'

'

'

'

'

'

'

'

81,593,000

91,608,000

89,291,000

'

Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Net Income

'

'

'

'

'

'

'

'

81,593,000

91,608,000

89,291,000

'

Other Comprehensive Loss, Net of Tax:

'

'

'

'

'

'

'

'

'

'

'

'

Postretirement Liability Adjustment

'

'

'

'

'

'

'

'

4,934,000

[1]

-1,842,000

[1]

-5,667,000

[1]

'

Unrealized Gain (Loss) on Available-for-Sale Securities

'

'

'

'

'

'

'

'

103,000

[1]

500,000

[1]

-360,000

[1]

'

Unrealized Gain (Loss) on Derivatives - Other

'

'

'

'

'

'

'

'

265,000

[1]

-92,000

[1]

-788,000

[1]

'

Other Comprehensive Income (Loss) - Net of Tax

'

'

'

'

'

'

'

'

10,345,000

[1]

-2,667,000

[1]

-6,626,000

[1]

'

Combined statutory tax rate

'

'

'

'

'

'

'

'

41.00%

'

'

'

Retained Earnings [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Retained Earnings - Beginning

'

'

'

382,127,000

'

'

'

'

382,127,000

'

'

'

Net Income

'

'

'

'

'

'

'

'

81,593,000

91,608,000

89,291,000

'

Dividends Declared - Common Stock

'

'

'

'

'

'

'

'

-57,679,000

-50,942,000

-44,975,000

'

Retained Earnings - Ending

406,041,000

'

'

'

382,127,000

'

'

'

406,041,000

382,127,000

'

'

Statement of Cash Flows [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

CASH PROVIDED BY OPERATING ACTIVITIES

'

'

'

'

'

'

'

'

159,535,000

117,826,000

191,357,000

'

CASH FLOWS FROM INVESTING ACTIVITIES:

'

'

'

'

'

'

'

'

'

'

'

'

Capital Expenditures

'

'

'

'

'

'

'

'

-316,644,000

-253,845,000

-193,119,000

'

Proceeds from Sale of Property, Plant & Equipment

'

'

'

'

'

'

'

'

0

29,000

3,500,000

'

Purchase of Company Owned Life Insurance

'

'

'

'

'

'

'

'

-5,149,000

-4,547,000

-4,628,000

'

Net Cash Used in Investing Activities

'

'

'

'

'

'

'

'

-245,792,000

-355,917,000

-224,175,000

'

CASH FLOWS FROM FINANCING ACTIVITIES:

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance of Long Term Debt

'

'

'

'

'

'

'

'

50,000,000

235,000,000

0

'

Payments for Issuance of Long term Debt

'

'

'

'

'

'

'

'

-411,000

-1,788,000

-43,000

'

Net Borrowing from Lines of Credits

'

'

'

'

'

'

'

'

65,000,000

17,500,000

70,714,000

'

Dividends on Common Stock

'

'

'

'

'

'

'

'

-57,679,000

-50,942,000

-44,975,000

'

Proceeds from Sale of Common Stock

'

'

'

'

'

'

'

'

54,028,000

70,241,000

13,436,000

'

Other

'

'

'

'

'

'

'

'

-501,000

880,000

379,000

'

Net Cash Provided by Financing Activities

'

'

'

'

'

'

'

'

85,437,000

235,191,000

37,993,000

'

Net (Decrease) Increase in Cash and Cash Equivalents

'

'

'

'

'

'

'

'

-820,000

-2,900,000

5,175,000

'

Cash and Cash Equivalents at Beginning of Period

'

'

'

4,638,000

'

'

'

7,538,000

4,638,000

7,538,000

2,363,000

'

Cash and Cash Equivalents at End of Period

3,818,000

'

'

'

4,638,000

'

'

'

3,818,000

4,638,000

7,538,000

'

Property Plant and Equipment:

'

'

'

'

'

'

'

'

'

'

'

'

Nonutility Property, Plant and Equipment, at cost

486,332,000

'

'

'

328,638,000

'

'

'

486,332,000

328,638,000

'

'

Accumulated Depreciation

-52,009,000

'

'

'

-36,208,000

'

'

'

-52,009,000

-36,208,000

'

'

Property, Plant and Equipment - Net

1,859,098,000

'

'

'

1,578,021,000

'

'

'

1,859,098,000

1,578,021,000

'

'

Investments:

'

'

'

'

'

'

'

'

'

'

'

'

Available-for-Sale Securities

8,716,000

'

'

'

7,538,000

'

'

'

8,716,000

7,538,000

'

'

Total Investments

130,104,000

'

'

'

101,266,000

'

'

'

130,104,000

101,266,000

'

'

Current Assets:

'

'

'

'

'

'

'

'

'

'

'

'

Cash and Cash Equivalents

3,818,000

'

'

'

4,638,000

'

'

'

3,818,000

4,638,000

7,538,000

'

Other

17,915,000

'

'

'

11,833,000

'

'

'

17,915,000

11,833,000

'

'

Total Current Assets

482,898,000

'

'

'

394,837,000

'

'

'

482,898,000

394,837,000

'

'

Other Noncurrent Assets

60,036,000

'

'

'

52,964,000

'

'

'

60,036,000

52,964,000

'

'

Total Assets

2,924,855,000

'

'

'

2,631,440,000

'

'

'

2,924,855,000

2,631,440,000

'

'

Equity:

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock SJI, Par Value $1.25, Authorized 60,000,000 shares, Outstanding - 32,715,042 (2013) shares and 31,653,262 (2012)

40,894,000

'

'

'

39,567,000

'

'

'

40,894,000

39,567,000

37,765,000

'

Premium on Common Stock

401,011,000

'

'

'

345,807,000

'

'

'

401,011,000

345,807,000

'

'

Treasury Stock (at par)

-186,000

'

'

'

-182,000

'

'

'

-186,000

-182,000

'

'

Accumulated Other Comprehensive Loss

-20,760,000

[1]

'

'

'

-31,105,000

[1]

'

'

'

-20,760,000

[1]

-31,105,000

[1]

'

'

Retained Earnings

406,041,000

'

'

'

382,127,000

'

'

'

406,041,000

382,127,000

'

'

Total Equity

827,000,000

'

'

'

736,214,000

'

'

'

827,000,000

736,214,000

'

'

Long-Term Debt

701,400,000

[2]

'

'

'

626,400,000

[2]

'

'

'

701,400,000

[2]

626,400,000

[2]

'

'

Current Liabilities:

'

'

'

'

'

'

'

'

'

'

'

'

Notes Payable - Banks

353,900,000

'

'

'

338,900,000

'

'

'

353,900,000

338,900,000

'

'

Accounts Payable

259,757,000

'

'

'

193,331,000

'

'

'

259,757,000

193,331,000

'

'

Other Current Liabilities

9,210,000

'

'

'

11,127,000

'

'

'

9,210,000

11,127,000

'

'

Total Current Liabilities

764,973,000

'

'

'

651,844,000

'

'

'

764,973,000

651,844,000

'

'

Other Noncurrent Liabilities

16,551,000

'

'

'

19,222,000

'

'

'

16,551,000

19,222,000

'

'

Total Capitalization and Liabilities

2,924,855,000

'

'

'

2,631,440,000

'

'

'

2,924,855,000

2,631,440,000

'

'

Common stock, par value (in dollars per share)

$1.25

'

'

'

$1.25

'

'

'

$1.25

$1.25

'

'

Common Stock, authorized (in shares)

60,000,000

'

'

'

60,000,000

'

'

'

60,000,000

60,000,000

'

'

Common Stock, outstanding (in shares)

32,715,042

'

'

'

31,653,262

'

'

'

32,715,042

31,653,262

30,212,453

29,872,825

SOUTH JERSEY INDUSTRIES, INC. [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Income Statement [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Operating Revenues

'

'

'

'

'

'

'

'

16,269,000

15,449,000

13,117,000

'

Operating Expenses:

'

'

'

'

'

'

'

'

'

'

'

'

Operations

'

'

'

'

'

'

'

'

14,979,000

13,869,000

12,390,000

'

Depreciation

'

'

'

'

'

'

'

'

260,000

183,000

160,000

'

Energy and Other Taxes

'

'

'

'

'

'

'

'

465,000

419,000

611,000

'

Total Operating Expenses

'

'

'

'

'

'

'

'

15,704,000

14,471,000

13,161,000

'

Operating Income

'

'

'

'

'

'

'

'

565,000

978,000

-44,000

'

Other Income:

'

'

'

'

'

'

'

'

'

'

'

'

Equity in Earnings of Subsidiaries

'

'

'

'

'

'

'

'

82,389,000

92,776,000

89,859,000

'

Other

'

'

'

'

'

'

'

'

5,459,000

3,270,000

2,688,000

'

Total Other Income

'

'

'

'

'

'

'

'

87,848,000

96,046,000

92,547,000

'

Interest Charges

'

'

'

'

'

'

'

'

6,004,000

4,219,000

2,648,000

'

Income Taxes

'

'

'

'

'

'

'

'

20,000

29,000

-4,000

'

Income from Continuing Operations

'

'

'

'

'

'

'

'

82,389,000

92,776,000

89,859,000

'

Equity in Undistributed Earnings of Discontinued Subsidiaries

'

'

'

'

'

'

'

'

-796,000

-1,168,000

-568,000

'

Net Income

'

'

'

'

'

'

'

'

81,593,000

91,608,000

89,291,000

'

Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Net Income

'

'

'

'

'

'

'

'

81,593,000

91,608,000

89,291,000

'

Other Comprehensive Loss, Net of Tax:

'

'

'

'

'

'

'

'

'

'

'

'

Postretirement Liability Adjustment

'

'

'

'

'

'

'

'

4,934,000

[3]

-1,842,000

[3]

-5,667,000

[3]

'

Unrealized Gain (Loss) on Available-for-Sale Securities

'

'

'

'

'

'

'

'

103,000

[3]

500,000

[3]

-360,000

[3]

'

Unrealized Gain (Loss) on Derivatives - Other

'

'

'

'

'

'

'

'

5,308,000

[3]

-1,325,000

[3]

-599,000

[3]

'

Other Comprehensive Income (Loss) - Net of Tax

'

'

'

'

'

'

'

'

10,345,000

[3]

-2,667,000

[3]

-6,626,000

[3]

'

Comprehensive Income Attributable to South Jersey Industries, Inc. Shareholders

'

'

'

'

'

'

'

'

91,938,000

88,941,000

82,665,000

'

Combined statutory tax rate

'

'

'

'

'

'

'

'

41.00%

41.00%

'

'

Retained Earnings [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Retained Earnings - Beginning

'

'

'

382,127,000

'

'

'

341,677,000

382,127,000

341,677,000

297,473,000

'

Net Income

'

'

'

'

'

'

'

'

81,593,000

91,608,000

89,291,000

'

Retained Earnings (Accumulated Deficit) After Net Income Before Dividends Declared

463,720,000

'

'

'

433,285,000

'

'

'

463,720,000

433,285,000

386,764,000

'

Dividends Declared - Common Stock

'

'

'

'

'

'

'

'

-57,679,000

-51,158,000

-45,087,000

'

Retained Earnings - Ending

406,041,000

'

'

'

382,127,000

'

'

'

406,041,000

382,127,000

341,677,000

'

Statement of Cash Flows [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

CASH PROVIDED BY OPERATING ACTIVITIES

'

'

'

'

'

'

'

'

1,316,000

1,840,000

14,179,000

'

CASH FLOWS FROM INVESTING ACTIVITIES:

'

'

'

'

'

'

'

'

'

'

'

'

Net (Advances to) Repayment from Associated Companies

'

'

'

'

'

'

'

'

-68,900,000

-174,593,000

22,957,000

'

Capital Expenditures

'

'

'

'

'

'

'

'

-360,000

-454,000

-299,000

'

Proceeds from Sale of Property, Plant & Equipment

'

'

'

'

'

'

'

'

6,000

29,000

0

'

Purchase of Company Owned Life Insurance

'

'

'

'

'

'

'

'

-5,149,000

-4,547,000

-4,628,000

'

Investment in Affiliate

'

'

'

'

'

'

'

'

-25,000,000

0

0

'

Net Cash Used in Investing Activities

'

'

'

'

'

'

'

'

-99,403,000

-179,565,000

18,030,000

'

CASH FLOWS FROM FINANCING ACTIVITIES:

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance of Long Term Debt

'

'

'

'

'

'

'

'

0

115,000,000

0

'

Payments for Issuance of Long term Debt

'

'

'

'

'

'

'

'

0

-665,000

0

'

Net Borrowing from Lines of Credits

'

'

'

'

'

'

'

'

101,600,000

42,000,000

3,013,000

'

Dividends on Common Stock

'

'

'

'

'

'

'

'

-57,679,000

-50,942,000

-44,975,000

'

Proceeds from Sale of Common Stock

'

'

'

'

'

'

'

'

54,028,000

70,241,000

13,436,000

'

Net Cash Provided by Financing Activities

'

'

'

'

'

'

'

'

97,949,000

175,634,000

-28,526,000

'

Net (Decrease) Increase in Cash and Cash Equivalents

'

'

'

'

'

'

'

'

-138,000

-2,091,000

3,683,000

'

Cash and Cash Equivalents at Beginning of Period

'

'

'

1,969,000

'

'

'

4,060,000

1,969,000

4,060,000

377,000

'

Cash and Cash Equivalents at End of Period

1,831,000

'

'

'

1,969,000

'

'

'

1,831,000

1,969,000

4,060,000

'

Cash Dividends Paid to Parent Company

'

'

'

'

'

'

'

'

0

0

12,700,000

'

Property Plant and Equipment:

'

'

'

'

'

'

'

'

'

'

'

'

Nonutility Property, Plant and Equipment, at cost

1,506,000

'

'

'

1,165,000

'

'

'

1,506,000

1,165,000

'

'

Accumulated Depreciation

-752,000

'

'

'

-510,000

'

'

'

-752,000

-510,000

'

'

Property, Plant and Equipment - Net

754,000

'

'

'

655,000

'

'

'

754,000

655,000

'

'

Investments:

'

'

'

'

'

'

'

'

'

'

'

'

Investments in Subsidiaries

887,671,000

'

'

'

770,127,000

'

'

'

887,671,000

770,127,000

'

'

Available-for-Sale Securities

21,000

'

'

'

18,000

'

'

'

21,000

18,000

'

'

Total Investments

887,692,000

'

'

'

770,145,000

'

'

'

887,692,000

770,145,000

'

'

Current Assets:

'

'

'

'

'

'

'

'

'

'

'

'

Cash and Cash Equivalents

1,831,000

'

'

'

1,969,000

'

'

'

1,831,000

1,969,000

4,060,000

'

Receivable from Associated Companies

358,620,000

'

'

'

289,635,000

'

'

'

358,620,000

289,635,000

'

'

Accounts Receivable

46,000

'

'

'

16,000

'

'

'

46,000

16,000

'

'

Other

1,510,000

'

'

'

3,401,000

'

'

'

1,510,000

3,401,000

'

'

Total Current Assets

362,007,000

'

'

'

295,021,000

'

'

'

362,007,000

295,021,000

'

'

Other Noncurrent Assets

35,882,000

'

'

'

29,624,000

'

'

'

35,882,000

29,624,000

'

'

Total Assets

1,286,335,000

'

'

'

1,095,445,000

'

'

'

1,286,335,000

1,095,445,000

'

'

Equity:

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock SJI, Par Value $1.25, Authorized 60,000,000 shares, Outstanding - 32,715,042 (2013) shares and 31,653,262 (2012)

'

'

'

'

39,567,000

'

'

'

'

39,567,000

'

'

Premium on Common Stock

401,011,000

'

'

'

345,807,000

'

'

'

401,011,000

345,807,000

'

'

Treasury Stock (at par)

-186,000

'

'

'

-182,000

'

'

'

-186,000

-182,000

'

'

Accumulated Other Comprehensive Loss

-20,760,000

'

'

'

-31,105,000

'

'

'

-20,760,000

-31,105,000

'

'

Retained Earnings

406,041,000

'

'

'

382,127,000

'

'

'

406,041,000

382,127,000

341,677,000

'

Total Equity

827,000,000

'

'

'

736,214,000

'

'

'

827,000,000

736,214,000

'

'

Long-Term Debt

165,000,000

'

'

'

115,000,000

'

'

'

165,000,000

115,000,000

'

'

Current Liabilities:

'

'

'

'

'

'

'

'

'

'

'

'

Notes Payable - Banks

288,400,000

'

'

'

236,800,000

'

'

'

288,400,000

236,800,000

'

'

Payable to Associated Companies

257,000

'

'

'

172,000

'

'

'

257,000

172,000

'

'

Accounts Payable

322,000

'

'

'

510,000

'

'

'

322,000

510,000

'

'

Other Current Liabilities

2,063,000

'

'

'

1,923,000

'

'

'

2,063,000

1,923,000

'

'

Total Current Liabilities

291,042,000

'

'

'

239,405,000

'

'

'

291,042,000

239,405,000

'

'

Other Noncurrent Liabilities

3,293,000

'

'

'

4,826,000

'

'

'

3,293,000

4,826,000

'

'

Total Capitalization and Liabilities

$1,286,335,000

'

'

'

$1,095,445,000

'

'

'

$1,286,335,000

$1,095,445,000

'

'

Common stock, par value (in dollars per share)

$1.25

'

'

'

$1.25

'

'

'

$1.25

$1.25

'

'

Common Stock, authorized (in shares)

60,000,000

'

'

'

60,000,000

'

'

'

60,000,000

60,000,000

'

'

Common Stock, outstanding (in shares)

32,715,042

'

'

'

31,653,262

'

'

'

32,715,042

31,653,262

'

'

[1]

Determined using a combined statutory tax rate of 41%.

[2]

Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000.

[3]

Determined using a combined statutory tax rate of 41%

Schedule_II_Valuation_and_Qual1

Schedule II - Valuation and Qualifying Accounts (Details) (Provision for Uncollectible Accounts [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Provision for Uncollectible Accounts [Member]	'		'		'
Movement in Valuation Allowances and Reserves [Roll Forward]	'		'		'
Beginning Balance	$5,924		$5,337		$8,071
Charged to Costs and Expenses	4,245		4,932		2,272
Charged to Other Accounts	-41	[1]	110	[1]	562	[1]
Deductions	4,274	[2]	4,455	[2]	5,568	[2]
Ending Balance	$5,854		$5,924		$5,337
[1]	Recoveries of accounts previously written off and minor adjustments.
[2]	Uncollectible accounts written off.