SOUTH JERSEY GAS 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 [Abstract]	'	'	'
Entity Registrant Name	'SOUTH JERSEY GAS Co	'	'
Entity Central Index Key	'0001035216	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Non-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	'	2,339,139	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$0

STATEMENTS_OF_INCOME

STATEMENTS OF INCOME (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement [Abstract]	'	'	'
Operating Revenues	$446,480	$421,874	$412,449
Operating Expenses:	'	'	'
Cost of Sales (Excluding depreciation)	200,081	188,710	187,866
Operations	85,805	78,425	68,149
Maintenance	13,135	13,615	13,122
Depreciation	33,775	31,062	30,358
Energy and Other Taxes	7,862	8,300	10,291
Total Operating Expenses	340,658	320,112	309,786
Operating Income	105,822	101,762	102,663
Other Income and Expense	3,797	2,617	3,429
Interest Charges	-12,550	-12,427	-18,922
Income Before Income Taxes	97,069	91,952	87,170
Income Taxes	-34,833	-33,711	-34,281
Net Income	$62,236	$58,241	$52,889

STATEMENTS_OF_COMPREHENSIVE_IN

STATEMENTS OF 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	$62,236		$58,241		$52,889
Other Comprehensive Gain (Loss), Net of Tax:	'		'		'
Postretirement Liability Adjustment	2,286	[1]	-1,683	[1]	-2,676	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities	103	[1]	500	[1]	-360	[1]
Unrealized Gain on Derivatives - Other	27	[1]	27	[1]	27	[1]
Other Comprehensive Gain (Loss) - Net of Tax	2,416	[1]	-1,156	[1]	-3,009	[1]
Comprehensive Income	$64,652		$57,085		$49,880
Combined statutory rate	41.00%		'		'
[1]	Determined using a combined statutory tax rate of 41%.

STATEMENTS_OF_CASH_FLOWS

STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net Cash Provided by (Used in) Operating Activities [Abstract]	'	'	'
Net Income	$62,236	$58,241	$52,889
Provided by Operating Activities:	'	'	'
Depreciation and Amortization	48,261	44,171	41,959
Provision for Losses on Accounts Receivable	4,232	4,775	1,410
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
Environmental Remediation Costs - Net of Recoveries	-438	-188	-13,612
Deferred and Noncurrent Income Taxes and Credits - Net	31,940	38,353	35,037
Gas Plant Cost of Removal	-6,092	-2,133	-1,590
Pension Contribution	-9,100	-19,757	0
Changes in:	'	'	'
Accounts Receivable	-20,574	-34,263	37,428
Inventories	-7,153	13,449	-6,285
Prepaid and Accrued Taxes - Net	9,456	6,451	-7,831
Other Prepayments and Current Assets	-476	430	-1,420
Gas Purchases Payable	9,306	-2,941	-9,048
Accounts Payable and Other Accrued Liabilities	-5,107	-8,803	21,079
Other Assets	-7,323	-10,980	-6,294
Other Liabilities	10,565	3,807	9,789
Net Cash Provided by Operating Activities	148,759	93,373	110,477
Cash Flows from Investing Activities:	'	'	'
Capital Expenditures	-161,498	-156,041	-142,570
Net Proceeds from Restricted Investments in Margin Account	588	930	2,103
Investment in Long-Term Receivables	-7,182	-6,243	-4,926
Proceeds from Long-Term Receivables	5,764	8,182	6,312
Net Cash Used in Investing Activities	-162,328	-153,172	-139,081
Cash Flows from Financing Activities:	'	'	'
Net (Repayments of) Borrowings from Lines of Credit	-36,600	-24,500	67,700
Proceeds from Issuance of Long-Term Debt	50,000	120,000	0
Principal Repayments of Long-Term Debt	-25,000	-35,000	-25,000
Premium for Early Retirement of Debt	0	-700	0
Payments for Issuance of Long-Term Debt	-411	-951	-43
Dividends on Common Stock	0	0	-12,664
Additional Investment by Shareholder	25,000	0	0
Excess Tax Benefit (Tax Deficiency) from Restricted Stock Plan	-78	124	85
Net Cash Provided by Financing Activities	12,911	58,973	30,078
Net (Decrease) Increase in Cash and Cash Equivalents	-658	-826	1,474
Cash and Cash Equivalents at Beginning of Period	2,678	3,504	2,030
Cash and Cash Equivalents at End of Period	2,020	2,678	3,504
Supplemental Disclosures of Cash Flow Information	'	'	'
Interest (Net of Amounts Capitalized)	12,234	12,073	20,068
Income Taxes (Net of Refunds)	-5,056	-2,797	-1,044
Supplemental Disclosures of Noncash Investing Activities	'	'	'
Property and equipment acquired on account but not paid at year-end	$20,055	$11,069	$12,171

BALANCE_SHEETS

BALANCE SHEETS (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Property, Plant and Equipment:	'		'
Utility Plant, at original cost	$1,816,804		$1,658,790
Accumulated Depreciation	-392,029		-373,199
Property, Plant and Equipment - Net	1,424,775		1,285,591
Investments:	'		'
Available-for-Sale Securities	8,696		7,520
Restricted Investments	680		1,268
Total Investments	9,376		8,788
Current Assets:	'		'
Cash and Cash Equivalents	2,020		2,678
Accounts Receivable	60,317		49,071
Accounts Receivable - Related Parties	968		961
Unbilled Revenues	41,510		35,351
Provision for Uncollectibles	-4,553		-3,985
Natural Gas in Storage, average cost	20,811		13,896
Materials and Supplies, average cost	1,798		1,560
Deferred Income Taxes - Net	23,309		0
Prepaid Taxes	7,683		17,046
Derivatives - Energy Related Assets	1,222		464
Other Prepayments and Current Assets	3,819		3,343
Total Current Assets	158,904		120,385
Regulatory and Other Noncurrent Assets:	'		'
Regulatory Assets	296,081		352,656
Unamortized Debt Issuance Costs	6,523		6,663
Long-Term Receivables	10,252		9,336
Derivatives - Energy Related Assets	278		302
Other	2,937		2,738
Total Regulatory and Other Noncurrent Assets	316,071		371,695
Total Assets	1,909,126		1,786,459
Common Equity:	'		'
Common Stock, Par Value $2.50 per share: Authorized - 4,000,000 shares Outstanding - 2,339,139 shares	5,848		5,848
Other Paid-In Capital and Premium on Common Stock	225,972		201,050
Accumulated Other Comprehensive Loss	-10,869	[1]	-13,285	[1]
Retained Earnings	390,018		327,782
Total Common Equity	610,969		521,395
Long-Term Debt	454,000	[2]	425,000	[2]
Total Capitalization	1,064,969		946,395
Current Liabilities:	'		'
Notes Payable	65,500		102,100
Current Portion of Long-Term Debt	21,000	[2]	25,000	[2]
Accounts Payable - Commodity	24,232		14,926
Accounts Payable - Other	32,072		25,498
Accounts Payable - Related Parties	6,638		5,872
Derivatives - Energy Related Liabilities	711		2,615
Deferred Income Taxes - Net	0		10,432
Customer Deposits and Credit Balances	15,089		17,450
Environmental Remediation Costs	15,422		19,203
Taxes Accrued	1,767		1,674
Pension Benefits	1,241		1,236
Interest Accrued	6,039		6,277
Other Current Liabilities	5,629		6,492
Total Current Liabilities	195,340		238,775
Regulatory and Other Noncurrent Liabilities:	'		'
Regulatory Liabilities	60,949		56,517
Deferred Income Taxes - Net	380,975		310,357
Environmental Remediation Costs	104,070		88,207
Asset Retirement Obligations	41,178		38,892
Pension and Other Postretirement Benefits	48,197		89,193
Investment Tax Credits	360		618
Derivatives - Energy Related Liabilities	48		80
Derivatives - Other	3,735		7,761
Other	9,305		9,664
Total Regulatory and Other Noncurrent Liabilities	648,817		601,289
Commitments and Contingencies (Note 9)	'		'
Total Capitalization and Liabilities	$1,909,126		$1,786,459
[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, $10,909; 2016, $27,909; 2017, $15,909; 2018, $38,909 .Our long-term debt agreements contain no financial covenants.

BALANCE_SHEETS_Parenthetical

BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]	'	'
Common stock, par value (in dollars per share)	$2.50	$2.50
Common stock, shares authorized	4,000,000	4,000,000
Common stock, shares outstanding	2,339,139	2,339,139

STATEMENTS_OF_CHANGES_IN_COMMO

STATEMENTS OF CHANGES IN COMMON EQUITY AND COMPREHENSIVE INCOME (USD $)		Total	Common Stock [Member]	Other Paid-In Capital and Premium on Common Stock [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]
In Thousands, unless otherwise specified
Balance at Dec. 31, 2010		$426,885	$5,848	$200,841	($9,120)	$229,316
Increase (Decrease) in Stockholders' Equity [Roll Forward]		'	'	'	'	'
Net Income		52,889	'	'	'	52,889
Other Comprehensive (Loss) Income, Net of Tax	[1]	-3,009	'	'	-3,009	'
Cash Dividends Declared b Common Stock		-12,664	'	'	'	-12,664
Additional Investment by Shareholder		0	'	0	'	'
Excess Tax Benefit from Restricted Stock Plan		85	'	85	'	'
Balance at Dec. 31, 2011		464,186	5,848	200,926	-12,129	269,541
Increase (Decrease) in Stockholders' Equity [Roll Forward]		'	'	'	'	'
Net Income		58,241	'	'	'	58,241
Other Comprehensive (Loss) Income, Net of Tax	[1]	-1,156	'	'	-1,156	'
Cash Dividends Declared b Common Stock		0	'	'	'	0
Additional Investment by Shareholder		0	'	0	'	'
Excess Tax Benefit from Restricted Stock Plan		124	'	124	'	'
Balance at Dec. 31, 2012		521,395	5,848	201,050	-13,285	327,782
Increase (Decrease) in Stockholders' Equity [Roll Forward]		'	'	'	'	'
Net Income		62,236	'	'	'	62,236
Other Comprehensive (Loss) Income, Net of Tax	[1]	2,416	'	'	2,416	'
Cash Dividends Declared b Common Stock		0	'	'	'	0
Additional Investment by Shareholder		25,000	'	25,000	'	'
Excess Tax Benefit from Restricted Stock Plan		-78	'	-78	'	'
Additional Statement Information [Abstract]		'	'	'	'	'
Combined statutory rate		41.00%	'	'	'	'
Balance at Dec. 31, 2013		$610,969	$5,848	$225,972	($10,869)	$390,018
[1]	Determined using a combined statutory tax rate of 41%.

STATEMENTS_OF_CHANGES_IN_COMMO1

STATEMENTS OF CHANGES IN COMMON 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]	'		'		'
Beginning balance	($13,285)	[1]	'		'
Changes During Year	2,416	[1]	-1,156	[1]	-3,009	[1]
Ending balance	-10,869	[1]	-13,285	[1]	'
Postretirement Liability Adjustment [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Beginning balance	-12,958	[1]	-11,275	[1]	-8,599	[1]
Changes During Year	2,286	[1]	-1,683	[1]	-2,676	[1]
Ending balance	-10,672	[1]	-12,958	[1]	-11,275	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Beginning balance	294	[1]	-206	[1]	154	[1]
Changes During Year	103	[1]	500	[1]	-360	[1]
Ending balance	397	[1]	294	[1]	-206	[1]
Unrealized Gain (Loss) on Derivatives [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Beginning balance	-621	[1]	-648	[1]	-675	[1]
Changes During Year	27	[1]	27	[1]	27	[1]
Ending balance	-594	[1]	-621	[1]	-648	[1]
Accumulated Other Comprehensive Income (Loss) [Member]	'		'		'
Change In Accumulated Other Comprehensive Loss Balances [Roll Forward]	'		'		'
Beginning balance	-13,285	[1]	-12,129	[1]	-9,120	[1]
Changes During Year	2,416	[1]	-1,156	[1]	-3,009	[1]
Ending balance	($10,869)	[1]	($13,285)	[1]	($12,129)	[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:
	The Entity - South Jersey Industries, Inc. (SJI) owns all of the outstanding common stock of South Jersey Gas Company (SJG). In our opinion, the financial statements reflect all normal and recurring adjustments needed to fairly present our financial position and operating results at the dates and for the periods presented.
	Certain reclassifications have been made to the prior 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 4.
	Equity Investments - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on our balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss.  An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary.   No impairment losses were recorded on Investments during 2013, 2012 or 2011.
	Estimates and Assumptions - We prepare our financial statements to conform with accounting principles generally accepted in the United States of America (GAAP). Management makes estimates and assumptions that affect the amounts reported in the financial statements and related disclosures. Therefore, actual results could differ from those estimates. Significant estimates include amounts related to regulatory accounting, energy derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition.
	Regulation - We are subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 3 for a detailed discussion of our rate structure and regulatory actions. We maintain our accounts according to the BPU’s prescribed Uniform System of Accounts. We follow the accounting for regulated enterprises prescribed by the FASB ASC Topic 980 – “Regulated Operations.”  In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 4 for a detailed discussion of regulatory assets and liabilities.
	Operating Revenues - Gas revenues are recognized in the period the commodity is delivered to customers. For retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas delivered from the date of the last meter reading to the end of the month.
	Revenue and Throughput-Based Taxes - We collect certain revenue-based energy taxes from our customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). We also collect 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 revenues 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 2013 and 2012 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.
	Natural Gas in Storage – Natural Gas in Storage is reflected at average cost on the balance sheets, and represents natural gas that will be utilized in the ordinary course of business.
	Property, Plant & Equipment - For regulatory purposes, utility plant is stated at original cost, which may be different than our cost if the assets were acquired from another regulated entity. The cost of adding, replacing and renewing property is charged to the appropriate plant account. Utility Plant balances as of December 31, 2013 and 2012 were comprised of the following (in thousands):
		2013			2012
	Utility Plant:
	Production Plant	$	296		$	296
	Storage Plant	22,538			20,316
	Transmission Plant	248,074			250,886
	Distribution Plant	1,417,939			1,297,619
	General Plant	53,162			49,586
	Other Plant	1,855			1,855
	Utility Plant in Service	1,743,864			1,620,558
	Construction Work in Progress	72,940			38,232
	Total Utility Plant	$	1,816,804		$	1,658,790
	The increase in Utility Plant in Service is related to projects for distribution, some of which are part of the Company's Capital Investment Recovery Tracker (CIRT) and Accelerated Infrastructure Replacement Program (AIRP), as discussed under Note 3. The increase in Construction Work in Progress is primarily related to information technology projects.
	Asset Retirement Obligations - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations we have to cut and cap our gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.
	ARO activity during 2013 and 2012 was as follows (in thousands):
		2013			2012
	ARO as of January 1,	$	38,892		$	29,388
	Accretion	1,514			1,870
	Additions	743			989
	Settlements	(1,630		)	(1,603		)
	Revisions in Estimated Cash Flows *	1,659			8,248
	ARO as of December 31,	$	41,178		$	38,892
	* 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.
	Capitalized Interest - We capitalize interest on construction at the rate of return on rate base utilized by the BPU to set rates in our last base rate proceeding (See Note 3). Capitalized interest is included in Utility Plant on the balance sheets. Interest Charges are presented net of capitalized interest on the statements of income.  We capitalized interest of $8.2 million in 2013, $6.5 million in 2012 and $1.1 million in 2011. The increase in 2013 represents the interest on the Company's investment in Utility Plant under the BPU-approved CIRT and AIRP programs. Under the CIRT and AIRP, qualified capital expenditures continued to accrue interest on construction until such projects were rolled into customer rates and recovery of the expenditures commenced.
	All CIRT program investments have been rolled into rate base and the CIRT program is now concluded. See Note 3 for additional discussion of the CIRT programs.
	Impairment of Long-Lived Assets - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the years ended 2013, 2012 and 2011, no significant impairments were identified.
	Derivative Instruments - SJG, through its affiliate, South Jersey Resources Group (SJRG) and another counterparty, uses a variety of derivative instruments to limit its exposure to market risk in accordance with strict guidelines (See Note 14).  These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives – Energy Related Assets or Derivatives – Energy Related Liabilities on the balance sheets.  The costs or benefits of these short-term contracts are recoverable through SJG’s Basic Gas Supply Service (BGSS) clause, subject to BPU approval.  As a result, the net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the balance sheets.
	SJG has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt.  These interest rate derivatives, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives-Other on the balance sheets.  The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates.  Subject to BPU approval, the market value upon termination of these interest rate derivatives can be recovered in rates and, therefore, these unrealized losses have been included in Other Regulatory Assets in the balance sheets.
	Income Taxes - Deferred income taxes are provided for all significant temporary differences between the book and taxable basis of assets and liabilities in accordance with FASB ASC Topic 740 – “Income Taxes” (See Note 6). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized.
	Cash and Cash Equivalents - For purposes of reporting cash flows, highly liquid investments with original maturities of three months or less are considered cash equivalents.
	NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2013, 2012 or 2011 had, or is expected to have, a material impact on the financial statements.
	In January 2012, the FASB issued Accounting Standards Update (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 was 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 was 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_PLANS

STOCK-BASED COMPENSATION PLANS	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
STOCK-BASED COMPENSATION PLANS	'
	STOCK-BASED COMPENSATION PLANS:
	Officers and other key employees of SJG participate in the Stock Option, Stock Appreciation Rights and Restricted Stock Award Plan ("Plan") of SJI. Restricted shares issued under this plan vest over a three-year period and are subject to SJI achieving certain market or 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 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.
	We are allocated a portion of SJI's compensation cost during the vesting period.  We accrue a liability and record compensation cost over the requisite three-year service period based on the grant date fair value as described above for each type of grant. Upon vesting, we make a cash payment to SJI equal to the amounts accrued as compensation cost during the vesting period. Since the inception of the Plan, our expense recognition policy has been consistent with the expense recognition policy at SJI.
	The following table summarizes the SJI nonvested restricted stock awards pertaining to SJG outstanding at December 31, 2013, and the assumptions used to estimate the fair value of the awards:
	Grant Date		Shares		Fair Value		Expected		Risk-Free
			Outstanding		Per Share		Volatility		Interest Rate
	Jan. 2012 - TSR		3,533		$	51.23	22.5	%	0.43	%
	Jan. 2012 - EPS		3,533		$	56.93	n/a		n/a
	Jan. 2013 - TSR		4,001		$	44.38	21.1	%	0.4	%
	Jan. 2013 - EPS		4,001		51.18		n/a		n/a
	Expected volatility is based on the actual volatility of SJI’s share price over the preceding three year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three year term of the Officers' and other key employees' restricted shares. As notional dividend equivalents are credited to the holders, which are reinvested during the three year service period, no reduction to the fair value of the award is required.
	The cost for restricted stock awards was $0.4 million in each of the years 2013, 2012 and 2011. Of these costs, $0.2 million was capitalized to Utility Plant in each of those years.
	As of December 31, 2013, there was $0.4 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:
		Shares		Weighted
				Average
				Grant Date
				Fair Value
	Nonvested Shares Outstanding, January 1, 2013	15,108		$	52.55
	Granted	9,324		$	47.78
	Vested*	(7,116	)	$	50.94
	Cancelled / Forfeited	(2,248	)	$	50.02
	Nonvested Shares Outstanding, December 31, 2013	15,068		$	50.73
	* Performance targets during the 3-year vesting period were not attained for the January 2011 grant. As a result, no shares will be awarded in 2014.
	During 2013, SJG awarded 12,901 shares that had vested at December 31, 2012, to its officers and other key employees at a market value of $0.6 million. During 2012, SJG awarded 7,098 shares at a market value of $0.4 million. SJG has a policy of making cash payments to SJI to satisfy its obligations under this plan. Cash payments to SJI during 2013 and 2012 were approximately $0.4 million and $0.3 million, respectively, relating to stock awards. Additionally, a change in control could result in the nonvested shares becoming nonforfeitable or immediately payable in cash.

RATES_AND_REGULATORY_ACTIONS

RATES AND REGULATORY ACTIONS	12 Months Ended
	Dec. 31, 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, we filed a base rate case with the BPU to increase our base rates to obtain a certain level of return on our capital investments. We expect the base rate case to be concluded during 2014. Other than the CIRT items discussed above, we have not sought a base rate increase from the BPU since the implementation of our base rate case approved in September 2010.
	Rate Mechanisms - Our tariff, a schedule detailing the terms, conditions and rate information applicable to our 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 us to recover all prudently incurred gas costs. BGSS charges to customers can be either monthly or periodic (annual). Monthly BGSS charges are applicable to large use customers and are referred to as monthly because the rate changes on a monthly basis pursuant to a BPU-approved formula based on commodity market prices. Periodic BGSS charges are applicable to lower usage customers, which include all of our residential customers, and are evaluated at least annually by the BPU. However, to some extent, more frequent rate changes to the periodic BGSS are allowed. We collect gas costs from customers on a forecasted basis and defer periodic over/under recoveries to the following BGSS year, which runs from October 1 through September 30. If we are in a net cumulative undercollected position, gas costs deferrals are reflected on the balance sheet as a regulatory asset. If we are in a net
	cumulative overcollected position, amounts due back to customers are reflected on the balance sheet as a regulatory liability. We pay interest on net overcollected BGSS balances at the rate of return on rate base utilized by the BPU to set rates in our last base rate proceeding.
	Regulatory actions regarding the BGSS were as follows:
	•	March 2011 - We credited the accounts of our periodic BGSS customers with refunds totaling $21.1 million due to gas costs that were lower than projected during the winter season.
	•	June 2011 - We filed our 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 - We credited the accounts of our 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 - We filed our 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 - We credited the accounts of our periodic BGSS customers with refunds totaling $9.4 million due to gas costs that were lower than projections.
	•	May 2013 - We filed our 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 - We credited the accounts of our 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 our profit margin on the number of customers rather than the amount of natural gas distributed to customers. In October 2006, the BPU approved the 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, we record adjustments to earnings based on weather and customer usage factors, as incurred. Subsequent to each year, we make 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 - We made our 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 - We made our 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 - We filed a joint petition with another utility requesting modification to, and the continuation of, the CIP program effective October 1, 2013.
	•	May 2013 - We made our 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, we 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 we be allowed to earn a return of, and a return on, our 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, we recorded adjustments to earnings based on actual CIRT program expenditures, as incurred.  Annually we 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 the Company to accelerate an additional $60.3 million of capital spending into 2011 and 2012. Under CIRT II, the Company 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, the Company is permitted to earn a return on CIRT II investments until the roll in is approved and recovery commences.
	•	June 2011 - The Company 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 - The Company 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 the Company to accelerate an incremental $35.0 million of capital spending through December 2012.
	•	October 2012 - The Company 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, the company filed a petition to implement a five-year, $250.0 million Accelerated Infrastructure Replacement Program 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, we 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, we 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 we were permitted to invest $17.0 million over two years in energy efficiency measures to be installed in customer homes and businesses. We also recover 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 - We 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 - We filed our 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 October 1, 2012.
	•	October 2011 - We 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 - We filed a petition requesting the approval of a new Energy Efficiency Program (“EEP II”) and to continue our 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 - We 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 - we filed our 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 us 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 - We made our 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 - We made our 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 - We made our 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 12). The BPU allows us 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, we reflected the unamortized remediation costs of $29.9 million and $37.9 million, respectively, on the balance sheet under Regulatory Assets (See Note 4). Since implementing the RAC in 1992, we have recovered $92.6 million through rates.
	New Jersey Clean Energy Program (NJCEP) - This mechanism recovers costs associated with our 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 ongoing basis.
	Separate regulatory actions regarding the USF were as follows:
	•	June 2011 - We made our 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 our 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. Our portion of the total is approximately $5.4 million, which decreased rates effective November 1, 2011, resulting in a $0.5 million decrease to our annual USF recoveries.
	•	June 2012 - We made our 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 our 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. Our portion of the total is approximately $8.2 million, which decreased rates effective October 1, 2012, resulting in a $0.1 million decrease to our annual USF recoveries.
	•	June 2013 - We made our 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 our 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.  Our portion of the total is approximately $5.8 million, which decreased rates effective October 1, 2013, resulting in a $3.4 million decrease to our USF recoveries.
Other Regulatory Matters -
Unbundling - In 2000, the BPU approved full unbundling of our system. This allows all natural gas consumers to select their natural gas commodity supplier. As of December 31, 2013, 47,074 of our customers were purchasing their gas commodity from someone other than us. Customers choosing to purchase natural gas from providers other than the utility are charged for the cost of gas by the marketer. The resulting decrease in our revenues is offset by a corresponding decrease in gas costs. While customer choice can reduce utility revenues, it does not negatively affect our 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 we still recover cost of service, including certain deferred costs, through base rates.
Pipeline Integrity - In October 2005, we 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 us 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 our September 2010 base rate increase, we were permitted to recover previously deferred pipeline integrity costs incurred through September 2010.  In addition, we are authorized to defer future program costs, including related carrying costs, for recovery in our next base rate proceeding, subject to review by the BPU.  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 (See Note 4).
Superstorm Sandy - In June 2013, we 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_AND_LIABILIT

REGULATORY ASSETS AND LIABILITIES	12 Months Ended
	Dec. 31, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
REGULATORY ASSETS AND LIABILITIES	'
	REGULATORY ASSETS AND LIABILITIES:
	The discussion under Note 3, Rates and Regulatory Actions, is integral to the following explanations of specific regulatory assets and liabilities.
	Regulatory Assets consisted of the following items (in thousands):
		2013		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. We are currently permitted to recover interest on our Environmental Remediation Costs, Societal Benefit Costs Receivable, Energy Efficiency Tracker and Pipeline Integrity Costs, while the other assets are being recovered without a return on investment.
	Environmental Remediation Costs - We have two regulatory assets associated with environmental costs related to the cleanup of 12 sites where we or our predecessors previously operated gas manufacturing plants. The first asset, Environmental Remediation Cost: Expended - Net, represents what was actually spent to clean up the sites, less recoveries through the RAC and insurance carriers. These costs meet the deferral requirements of GAAP, as the BPU allows us to recover such expenditures through the RAC. The other asset, Environmental Remediation Cost: Liability for Future Expenditures, relates to estimated future expenditures required to complete the remediation of these sites. We recorded this estimated amount as a regulatory asset with the corresponding current and noncurrent liabilities on the balance sheets under the captions Current Liabilities and Regulatory and Other Noncurrent Liabilities. The BPU allows us to recover the deferred costs over seven-year periods after they are spent (See Notes 3 and 12).
	Deferred Asset Retirement Obligation Costs - This regulatory asset  resulted from the recording of asset retirement obligations (ARO) and additional utility plant, primarily related to a legal obligation we have for certain safety requirements upon the retirement of our gas distribution and transmission system. We recover asset retirement costs through rates charged to customers. All related accumulated accretion and depreciation amounts for these ARO represent timing differences in the recognition of retirement costs that we are currently recovering in rates and, as such, we are deferring such differences as regulatory assets.
	Deferred Pension and Other Postretirement Benefit Costs  - The BPU authorized us to recover costs related to postretirement benefits under the accrual method of accounting consistent with  GAAP.  We deferred amounts accrued prior to that authorization and amortized them as allowed by the BPU over 15 years through 2012. In 2006, our regulatory asset was increased by $37.1 million representing the recognition of the underfunded positions of our pension and other postretirement benefit plans.  Subsequent adjustments to this balance occur annually to reflect changes in the funded positions of these benefit plans caused by changes in actual plan experience as well as assumptions of future experience (See Note 11).
	Conservation Incentive Program Receivable - The impact of the CIP is recorded as an adjustment to earnings as incurred, while cash recovery under the CIP generally occurs during the subsequent CIP year (see Note 3).
	Societal Benefit Costs Receivable - This regulatory asset primarily represents cumulative costs less recoveries under the USF program (See Note 3).
	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.
	Energy Efficiency Tracker - This regulatory asset represents cumulative investments less recoveries under the Energy Efficiency Program (See Note 3).
	Deferred Interest Rate Contracts - These amounts represent the market value of interest rate derivatives as discussed further in Note 13.
	Pipeline Supplier Service Charges - This regulatory asset represents costs necessary to maintain adequate supply and system pressures, which are being recovered on a monthly basis through the BGSS over the term of the underlying supplier contracts (See Note 3).
	Pipeline Integrity Cost - As part of our September 2010 base rate increase, we were permitted to recover previously deferred pipeline integrity costs incurred through September 2010. In addition, we are authorized to defer future program costs, including related carrying costs, for recovery in our next base rate proceeding, subject to review by the BPU (see Note 3).
	Other Regulatory Assets - Some of the assets included in Other Regulatory Assets are currently being recovered from ratepayers as approved by the BPU. Management believes the remaining deferred costs are probable of recovery from ratepayers through future utility rates.
	Regulatory Liabilities at December 31 consisted of the following items (in thousands):
		2013		2012
	Excess Plant Removal Costs	$	40,029	$	45,593
	Deferred Revenue - 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 our September 2010 base rate increase, we are 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 our BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability (See Note 3). Derivative contracts used to hedge our natural gas purchases are also included in the BGSS, subject to BPU approval (See Note 14). 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.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	RELATED PARTY TRANSACTIONS:
	We conducted business with our parent, SJI, and several other related parties. A description of each of these affiliates and related transactions is as follows:
	SJI Services, LLC (SJIS) - a wholly owned subsidiary of SJI, provides services, such as information technology, human resources, corporate communications, materials purchasing and fleet management to SJI and all of its subsidiaries.
	South Jersey Energy Solutions, LLC (SJES) - a wholly owned subsidiary of SJI that serves as a holding company for all of SJI’s nonutility operating businesses:
	•	South Jersey Energy Company (SJE) - a wholly owned subsidiary of SJES and a third party energy marketer that acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers. We provide SJE with billing services. For SJE’s residential customers, for which we perform billing services, we purchase the related accounts receivable at book value less a factor for potential uncollectible accounts, and assume all risk associated with collection.
	•	South Jersey Resources Group, LLC (SJRG) - a wholly owned subsidiary of SJES and a wholesale gas and risk management business that supplies natural gas storage, commodity and transportation to retail marketers, utility businesses and electricity generators in the mid-Atlantic, Appalachian and southern states. We sell natural gas for resale and capacity release to SJRG and also meet some of our gas purchasing requirements by purchasing natural gas from SJRG. Additionally, SJRG manages our market risk associated with fluctuations in the cost of natural gas by entering into financial derivative contracts on our behalf. The gain or loss associated with these derivative contracts is included in our BGSS and in the SJRG receivable and payable amounts shown below.
	•	Marina Energy LLC (Marina) - a wholly owned subsidiary of SJES and developer, owner and operator of energy related projects. We provide natural gas transportation services to Marina under BPU-approved tariffs.
	•	South Jersey Energy Service Plus, LLC (SJESP) - a wholly owned subsidiary of SJES and an appliance service company. We provide billing services to SJESP.
	Millennium Account Services, LLC (Millennium) - a partnership between SJI and Pepco Holdings, Inc, which reads our utility customers’ meters on a monthly basis for a fee.
	Sales of gas to SJRG and SJE comply with Section 284.02 of the Regulations of the Federal Energy Regulatory Commission (FERC).
	In addition to the above, we provide various administrative and professional services to SJI and each of the affiliates discussed above. Likewise, SJI and SJIS provide substantial administrative services on our behalf. For certain types of transactions, we served as central processing agents for the related parties discussed above. Amounts due to and due from these related parties for pass-through items are not considered material to the financial statements as a whole. A summary of these related party transactions, excluding pass-through items, included in Operating Revenues were as follows (in thousands):
		2013			2012			2011
	Operating Revenues/Affiliates:
	SJRG	$	1,390		$	884		$	6,532
	Other	1,299			851			716
	Total Operating Revenues/Affiliates	$	2,689		$	1,735		$	7,248
	Related party transactions, excluding pass-through items, included in Operating Expenses were as follows (in thousands):
		2013			2012			2011
	Costs of Sales/Affiliates
	(Excluding depreciation):
	SJRG	$	14,959		$	9,083		$	33,768
	Derivative Losses (See Note 1):
	SJRG	$	887		$	15,407		$	12,872
	Operations Expense/Affiliates:
	SJI	$	11,990		$	10,870		$	9,941
	SJIS	5,531			5,397			4,956
	Millennium	2,686			3,149			3,076
	Other	(428		)	(500		)	(448		)
	Total Operations Expense/Affiliates	$	19,779		$	18,916		$	17,525

INCOME_TAXES_AND_CREDITS

INCOME TAXES AND CREDITS	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
INCOME TAXES AND CREDITS	'
	INCOME TAXES AND CREDITS:
	Total income taxes applicable to operations differ from the tax that would have resulted by applying the statutory Federal income tax rate to pre-tax income for the following reasons (in thousands):
		2013			2012			2011
	Tax at Statutory Rate	$	33,974		$	32,183		$	30,510
	Increase (Decrease) Resulting from:
	State Income Taxes	4,833			5,302			5,316
	Amortization of Investment Tax Credits	(258		)	(287		)	(302		)
	ESOP Dividend	(1,058		)	(1,027		)	(956		)
	AFUDC	(916		)	(1,048		)	(729		)
	Amortization of Flowthrough Depreciation	—			—			526
	Other - Net	(1,742		)	(1,412		)	(84		)
	Net Income Taxes	$	34,833		$	33,711		$	34,281
	The provision for Income Taxes is comprised of the following (in thousands):
		2013			2012			2011
	Current:
	Federal	$	(53	)	$	(4,635	)	$	(924	)
	State	2,946			(7		)	168
	Total Current	2,893			(4,642		)	(756		)
	Deferred:
	Federal	27,707			30,477			27,329
	State	4,491			8,163			8,010
	Total Deferred	32,198			38,640			35,339
	Investment Tax Credits	(258		)	(287		)	(302		)
	Net Income Taxes	$	34,833		$	33,711		$	34,281
	Investment Tax Credits are deferred and amortized at the annual rate of 3%, which approximates the life of related assets.
	The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax liabilities at December 31 (in thousands):
		2013			2012
	Current:
	Net Operating Loss Carryforward	$	(27,600	)	$	(2,586	)
	Budget Billing - Customer Accounts	1,152			1,033
	Provision for Uncollectibles	(1,726		)	(1,409		)
	Conservation Incentive Program	4,631			13,942
	Section 461 Prepayments	1,156			930
	Other	(922		)	(1,478		)
	Current Deferred Tax (Asset) Liability - Net	$	(23,309	)	$	10,432
	Noncurrent:
	Book Versus Tax Basis of Property	$	371,684		$	323,470
	Deferred Fuel Costs - Net	1,330			3,325
	Environmental Remediation	14,392			17,643
	Deferred Regulatory Costs	13,665			15,374
	Deferred State Tax	(15,471		)	(15,106		)
	Investment Tax Credit Basis Gross-Up	(185		)	(318		)
	Deferred Pension & Other Post Retirement Benefits	24,218			39,174
	Pension & Other Post Retirement Benefits	(14,152		)	(28,846		)
	Deferred Revenues	(9,266		)	(8,922		)
	Net Operating Loss Carryforward	(8,764		)	(35,901		)
	Other	3,524			464
	Noncurrent Deferred Tax Liability – Net	$	380,975		$	310,357
	SJG is included in the consolidated federal income tax return filed by SJI. The actual taxes, including credits, are allocated by SJI to its subsidiaries, generally on a separate return basis except for net operating loss and credit carryforwards. As of December 31, 2013 there were no income taxes due from SJI. As of December 31, 2012 income taxes due from SJI were approximately $4.6 million and are included in the balance sheets under the caption, Prepaid Taxes.
	As of December 31, 2013, SJG has total federal net operating loss carryforwards of $103.7 million; $99.4 million of the federal NOL will expire in 2031 and $4.3 million will expire in 2032. A valuation allowance is recorded when it is more likely than not that any of our deferred income tax assets will not be realized. We believe that we will generate sufficient future taxable income to realize the income tax benefits related to our deferred tax assets.
	A reconciliation of unrecognized tax benefits is as follows (in thousands):
		2013			2012			2011
	Balance at January 1,	$	503		$	421		$	478
	Increase as a result of tax position taken in prior years	44			82			119
	Decrease due to a lapse in the statue of limitations	—			—			(90		)
	Settlements	—			—			(86		)
	Balance at December 31,	$	547		$	503		$	421
	The total unrecognized tax benefits as of December 31, 2013 were $0.5 million, not including $0.6 million of accrued interest and penalties.  The total unrecognized tax benefits as of December 31, 2012 were $0.5 million not including $0.6 million of accrued interest and penalties. The total unrecognized tax benefits as of December 31, 2011 were $0.4 million, not including $0.6 million of accrued interest and penalties. The amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate is not significant.  Our policy is to record interest and penalties related to unrecognized tax benefits as interest expense and other expense respectively. These amounts were not significant in 2013, 2012 or 2011. There have been no material changes to the unrecognized tax benefits during 2013, 2012 or 2011 and we do 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 taxes.  Federal income tax returns from 2009 forward and state income tax returns from 2012 forward are open and subject to examination.

LONGTERM_DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
LONG-TERM DEBT	'
	LONG-TERM DEBT:
	A schedule of our long-term debt as of December 31, including current maturities, is as follows (in thousands):
				2013			2012
	Long-Term Debt (A):
	First Mortgage Bonds: (B)
	4.46	%	Series due 2013 (C)	$	—		$	10,500
	5.027	%	Series due 2013 (C)	—			14,500
	4.52	%	Series due 2014	11,000			11,000
	5.115	%	Series due 2014	10,000			10,000
	5.387	%	Series due 2015	10,000			10,000
	5.437	%	Series due 2016	10,000			10,000
	4.6	%	Series due 2016	17,000			17,000
	4.657	%	Series due 2017	15,000			15,000
	7.97	%	Series due 2018	10,000			10,000
	7.125	%	Series due 2018	20,000			20,000
	5.587	%	Series due 2019	10,000			10,000
	3	%	Series due 2024	50,000			50,000
	3.03	%	Series due 2024	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 (D)	50,000			—
	3.74	%	Series due 2032	35,000			35,000
	5.55	%	Series due 2033	32,000			32,000
	6.213	%	Series due 2034	10,000			10,000
	5.45	%	Series due 2035	10,000			10,000
	Series A 2006 Tax-Exempt First Mortgage Bonds
	Variable Rate, due 2036 (E)			25,000			25,000
	Total Long-Term Debt Outstanding			475,000			450,000
	Less Current Maturities (A)			(21,000		)	(25,000		)
	Long-Term Debt			$	454,000		$	425,000
	(A)	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $10,909; 2016, $27,909; 2017, $15,909; 2018, $38,909 .Our long-term debt agreements contain no financial covenants.
	(B)	Our First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant.
	(C)	In July 2013, SJG called its $10.5 million, 4.46% Medium Term Notes (MTN) due July 2013 and $14.5 million, 5.027% MTN due September 2013.
	(D)	In November 2013, SJG issued $50.0 million of 4.01% aggregate principal amount of MTN due November 2030.
	(E)	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.
	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 30, 2014. As of December 31, 2013, $30.0 million was available under this program. In January 2014, SJG issued the remaining $30.0 million aggregate principle amount of 4.23% MTN's due January 2030. We retire debt when it is cost effective as permitted by the debt agreements.

FINANCIAL_INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
Investments, All Other Investments [Abstract]	'
FINANCIAL INSTRUMENTS	'
	FINANCIAL INSTRUMENTS:
	RESTRICTED INVESTMENTS - In accordance with the terms of our tax-exempt first mortgage bonds, unused proceeds are required to be escrowed pending approved construction expenditures. As of both December 31, 2013 and December 31, 2012, the escrowed proceeds, including interest earned, totaled $0.1 million. SJG established a margin account with SJRG in conjunction with SJG's risk management activities as detailed in Note 14. The funds provided by SJG will increase or decrease as the number and value of outstanding energy-related contracts held with SJRG changes. As of December 31, 2013 and December 31, 2012, the balance held with SJRG totaled $0.5 million and $1.1 million, respectively. During March 2013, SJG established a margin account with a counterparty in conjunction with SJG's risk management activities as detailed in Note 14. The funds provided by SJG will increase or decrease as the number and value of outstanding energy-related contracts held with this counterparty changes. The carrying amounts of the Restricted Investments approximate their fair value at December 31, 2013 and December 31, 2012, which would be included in Level 1 of the fair value hierarchy. (See Note 10 - 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 December 31, 2012, respectively.  The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Long-Term Receivables on the balance sheets.  The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.3 million as of both December 31, 2013 and December 31, 2012.  The annual amortization to interest is not material to SJG’s financial statements.  The carrying amounts of these receivables approximate their fair value at December 31, 2013 and December 31, 2012, which would be included in Level 2 of the fair value hierarchy. (See Note 10 - Fair Value of Financial Assets and Financial Liabilities).
	FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJG's financial instruments that are not carried at fair value, including those financial instruments disclosed in this footnote, approximate their fair values at December 31, 2013 and December 31, 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 SJG at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy. See Note 13 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJG's long-term debt, including current maturities, as of December 31, 2013 and December 31, 2012, were $486.5 million and $502.0 million, respectively.  The carrying amounts of SJG's long-term debt, including current maturities, as of December 31, 2013 and December 31, 2012, were $475.0 million and $450.0 million, respectively.

LINES_OF_CREDIT

LINES OF CREDIT	12 Months Ended
	Dec. 31, 2013
Line of Credit Facility [Abstract]	'
LINES OF CREDIT	'
	LINES OF CREDIT:
	Credit facilities and available liquidity as of December 31, 2013 were as follows (in thousands):
		Total Facility		Usage		Available Liquidity		Expiration Date
	Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	65,500	$	134,500	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total	$	210,000	$	65,500	$	144,500
	SJG renewed the uncommitted bank line of credit during the third quarter 2013. Also, SJG amended and extended its revolving credit facility during the third quarter of 2013; as a result, the maturity date was extended from May 2015 to May 2018.
	The SJG facility is provided by a syndicate of banks and contains one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the credit agreement) to not more than 0.65 to 1 measured at the end of each fiscal quarter.  SJG was 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 $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.
	Average borrowings outstanding under these credit facilities, not including letters of credit, during the twelve months ended December 31, 2013 and 2012 were $91.4 million and $142.4 million, respectively.  The maximum amount outstanding under these credit facilities, not including letters of credit, during the twelve months ended December 31, 2013 and 2012 were $121.9 million and $180.5 million, respectively.
	Based upon the existing credit facilities and a regular dialogue with our banks, we believe that there will continue to be sufficient credit available to meet our business’ future liquidity needs. Borrowings under these credit facilities are at market rates.  The weighted average interest rate on these borrowings, which changes daily, was 0.37% , 0.48% and 0.62% at December 31, 2013 , 2012 and 2011, respectively.

RETAINED_EARNINGS

RETAINED EARNINGS	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
RETAINED EARNINGS	'
	RETAINED EARNINGS:
	Various loan agreements contain potential restrictions regarding the amount of cash dividends or other distributions that we may pay on our common stock. As of December 31, 2013, these loan restrictions did not affect the amount that may be distributed from our retained earnings.
	SJG received a $25 million equity infusion from SJI in 2013. No equity infusions were received from SJI in 2012 or 2011.  Future equity contributions will occur on an as needed basis.

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:
	We participate in the defined benefit pension plans and other postretirement benefit plans of SJI. The pension plans provide annuity payments to the majority of full-time, regular employees upon retirement. Participation in the SJI qualified defined benefit pension plans was closed to new employees beginning in 2003; however, employees who are not eligible for these pension plans are eligible to receive an enhanced version of SJI’s defined contribution plan. Certain officers of SJG also participate in the non-funded supplemental executive retirement plan (SERP) of SJI, a non-qualified defined benefit pension plan. The other postretirement benefit plans provide health care and life insurance benefits to some retirees.
	Net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):
		Pension Benefits											Other Postretirement Benefits
		2013				2012				2011			2013				2012			2011
	Service Cost	$	4,487			$	3,718			$	3,048		$	771			$	704		$	675
	Interest Cost	7,886				8,008				7,828			2,221				2,443			2,621
	Expected Return on Plan Assets	(9,435		)		(8,249		)		(7,415		)	(2,158		)		(1,910		)	(2,040		)
	Amortization:
	Prior Service Cost (Credits)	208				207				219			(195		)		(195		)	(254		)
	Actuarial Loss	7,608				6,432				4,561			1,555				1,534			1,466
	Net Periodic Benefit Cost	10,754				10,116				8,241			2,194				2,576			2,468
	Capitalized Benefit Costs	(5,002		)		(4,684		)		(3,661		)	(1,172		)		(1,340		)	(1,222		)
	Affiliate SERP Allocations	(1,389		)		(1,107		)		(845		)	—				—			—
	Total Net Periodic Benefit Expense	$	4,363			$	4,325			$	3,735		$	1,022			$	1,236		$	1,246
	Capitalized benefit costs reflected in the table above relate to our construction program.
	Companies with publicly traded equity securities that sponsor a postretirement benefit plan are required to fully recognize, as an asset or liability, the overfunded or underfunded status of its benefit plans and recognize changes in the funded status in the year in which the changes occur. Changes in funded status are generally reported in Other Comprehensive Loss; however, since we recover all prudently incurred pension and postretirement benefit costs from our ratepayers, a significant portion of the charges resulting from the recording of additional liabilities under this statement are reported as regulatory assets (See Note 4).
	Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands):
		Regulatory Assets								Accumulated Other Comprehensive Loss (pre-tax)
		Pension Benefits				Other Postretirement Benefits				Pension Benefits			Other Postretirement Benefits
	Balance at January 1, 2012	$	61,811			$	26,435			$	19,061		$	—
	Amounts Arising during the Period:
	Net Actuarial Loss	11,599				2,089				4,788			—
	Amounts Amortized to Net Periodic Costs:
	Net Actuarial Loss	(4,490		)		(1,535		)		(1,941		)	—
	Prior Service (Cost) Credit	(207		)		195				—			—
	Balance at December 31, 2012	68,713				27,184				21,908			—
	Amounts Arising during the Period:
	Net Actuarial Gain	(20,554		)		(9,171		)		(1,576		)	—
	Amounts Amortized to Net Periodic Costs:
	Net Actuarial Loss	(5,319		)		(1,555		)		(2,289		)	—
	Prior Service (Cost) Credit	(208		)		194				—			—
	Balance at December 31, 2013	$	42,632			$	16,652			$	18,043		$	—
	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
	Net Actuarial Loss	$	2,007			$	—
	A reconciliation of the plans’ benefit obligations, fair value of plan assets, funded status and amounts recognized in our balance sheets follows (in thousands):
										Other
		Pension Benefits								Postretirement Benefits
		2013				2012				2013			2012
	Change in Benefit Obligations:
	Benefit Obligation at Beginning of Year	$	186,899			$	160,319			$	55,615		$	51,656
	Service Cost	4,487				3,718				771			704
	Interest Cost	7,886				8,008				2,221			2,443
	Actuarial (Gain) Loss	(11,514		)		21,990				(4,552		)	4,059
	Retiree Contributions	—				—				335			313
	Plan Amendments	—				—				—			—
	Benefits Paid	(7,090		)		(7,136		)		(3,475		)	(3,560		)
	Benefit Obligation at End of Year	$	180,668			$	186,899			$	50,915		$	55,615
	Change in Plan Assets:
	Fair Value of Plan Assets at Beginning of Year	$	119,391			$	91,738			$	32,694		$	28,942
	Actual Return on Plan Assets	20,049				13,853				5,101			3,880
	Employer Contributions	10,324				20,936				4,816			3,119
	Retiree Contributions	—				—				335			313
	Benefits Paid	(7,090		)		(7,136		)		(3,475		)	(3,560		)
	Fair Value of Plan Assets at End of Year	$	142,674			$	119,391			$	39,471		$	32,694
	Funded Status at End of Year:
	Accrued  Net Benefit Cost at End of Year	$	(37,994	)		$	(67,508	)		$	(11,444	)	$	(22,921	)
	Amounts Recognized in the Statement of Financial Position Consist of:
Current Liabilities	$	(1,241	)		$	(1,236	)		$	—		$	—
Noncurrent Liabilities	(36,753		)		(66,272		)		(11,444		)	(22,921		)
Net Amount Recognized at End of Year	$	(37,994	)		$	(67,508	)		$	(11,444	)	$	(22,921	)
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
Net Amount Recognized at End of Year	$	42,632			$	68,713			$	16,652		$	27,184
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
Net Actuarial Loss	$	18,043			$	21,908			$	—		$	—
The projected benefit obligation (PBO) and accumulated benefit obligation (ABO) of our qualified employee pension plans were $143.5 million and $131.4 million, respectively, as of December 31, 2013; and $149.5 million and $135.6 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 tables above. The PBO and ABO for our non-funded SERP were $37.2 million and $36.2 million, respectively, as of December 31, 2013; and $37.4 million and $35.7 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 our 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-				1-Percentage-
	Point Increase				Point Decrease
Effect on the Total of Service and Interest Cost	$	145			$	(115	)
Effect on Postretirement Benefit Obligation	$	2,406			$	(2,027	)
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, mid-cap and small-cap companies.  Fixed income securities include commingled common/collective trust funds, group annuity contracts for pension payments, and hedge funds.  Other types of investments include investments in private equity funds and real estate funds that follow several different strategies.
The strategy recognizes that risk and volatility are present to some degree with all types of investments.  We seek to avoid high levels of risk at the total fund level through diversification by asset class, style of manager, and sector and industry limits.  Specifically prohibited investments include, but are not limited to, venture capital, margin trading, commodities and securities of companies with less than $250.0 million capitalization (except in the small-cap portion of the fund where capitalization levels as low as $50.0 million are permissible).  These restrictions are only applicable to individual investment managers with separately managed portfolios and do not apply to mutual funds or commingled trusts.
SJG evaluated its pension and other postretirement benefit plans’ asset portfolios for the existence of significant concentrations of credit risk as of December 31, 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 SJG’s pension and other postretirement benefit plan assets.
GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques.  This hierarchy groups assets into three (3) distinct levels as fully described in Note 13, that will serve as the basis for presentation throughout the remainder of this Note.
The fair values of SJG’s pension plan assets at December 31, 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)	$	334			$	—			$	334		$	—
STIF-Type Instrument (b)	943				—				943			—
Equity securities:
Common/Collective Trust Funds – U.S. (a)	41,527				—				41,527			—
Common/Collective Trust Funds – International (a)	27,312				—				27,312			—
U.S. Large-Cap (c)	9,342				9,342				—			—
U.S. Mid-Cap (c)	3,313				3,313				—			—
International (c)	2,935				2,935				—			—
Fixed Income:
Common/Collective Trust Funds (a)	36,728				—				36,728			—
Guaranteed Insurance Contract (d)	9,071				—				—			9,071
Hedge Funds (e)	3,328				—				—			3,328
Other types of investments:
Private Equity Fund (f)	2,440				—				—			2,440
Common/Collective Trust Fund – Real Estate (g)	5,401				—				—			5,401
Total	$	142,674			$	15,590			$	106,844		$	20,240
Asset Category	Total				Level 1				Level 2			Level 3
As of December 31, 2012:
Cash / Cash Equivalents:
Common/Collective Trust Funds (a)	$	477			$	—			$	477		$	—
STIF-Type Instrument (b)	840				—				840			—
Equity securities:
Common/Collective Trust Funds – U.S. (a)	33,690				—				33,690			—
Common/Collective Trust Funds – International (a)	23,448				—				23,448			—
U.S. Large-Cap (c)	7,126				7,126				—			—
U.S. Mid-Cap (c)	4,194				4,194				—			—
U.S. Small-Cap (c)	8				8				—			—
International (c)	1,462				1,462				—			—
Fixed Income:
Common/Collective Trust Funds (a)	30,913				—				30,913			—
Guaranteed Insurance Contract (d)	9,898				—				—			9,898
Other types of investments:
Private Equity Fund (f)	2,557				—				—			2,557
Common/Collective Trust Fund – Real Estate (g)	4,778				—				—			4,778
Total	$	119,391			$	12,790			$	89,368		$	17,233
(a)	This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate).  These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable.  Also included in these funds are interest rate swaps, asset backed securities, mortgage backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments.
(b)	This category represents short-term investment funds held for the purpose of funding disbursement payment arrangements.  Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information.  Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments.
(c)	This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy.  These common stocks are actively traded on exchanges and price quotes for these shares are readily available.  These common stocks are classified as Level 1 investments.
(d)	This category represents SJI’s Group Annuity contracts with a nationally recognized life insurance company.  The contracts are the assets of the plan, while the underlying assets of the contracts are owned by the contract holder.  Valuation is based on a formula and calculation specified within the contract.  Since the valuation is based on the reporting entity’s own assumptions, these contracts are classified as Level 3 investments.
(e)	This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in the U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments.
(f)	This category represents a limited partnership which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds.  Fund valuations are reported on a 90 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 2 investments.
Fair Value Measurement Using Significant
Unobservable Inputs (Level 3)
(In thousands)
	Guaranteed				Hedge				Private			Real				Total
	Insurance				Funds				Equity			Estate
	Contract								Funds
Balance at January 1, 2012	$	9,647			$	—			$	2,525		$	4,291			$	16,463
Actual return on plan assets:
Relating to assets still held at the reporting date	1,082				—				(122		)	487				1,447
Relating to assets sold during the period	(10		)		—				480			—				470
Purchases, Sales and Settlements	(821		)		—				(326		)	—				(1,147		)
Balance at December 31, 2012	$	9,898			$	—			$	2,557		$	4,778			$	17,233
Actual return on plan assets:
Relating to assets still held at the reporting date	(68		)		124				80			623				759
Relating to assets sold during the period	14				—				345			—				359
Purchases, Sales and Settlements	(773		)		3,204				(542		)	—				1,889
Balance at December 31, 2013	$	9,071			$	3,328			$	2,440		$	5,401			$	20,240
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 SJG’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)	$	12,412			$	—			$	12,412		$	—
Common/Collective Trust Funds - International (a)	10,031				—				10,031			—
Mutual Fund - U.S. Large-Cap (b)	2,814				2,814				—			—
Fixed Income:
Common/Collective Trust (a)	14,214				—				14,214			—
Total	$	39,471			$	2,814			$	36,657		$	—
Asset Category	Total				Level 1				Level 2			Level 3
As of December 31, 2012:
Equity Securities:
Common/Collective Trust Funds - U.S. (a)	$	9,972			$	—			$	9,972		$	—
Common/Collective Trust Funds - International (a)	8,475				—				8,475			—
Mutual Fund - U.S. Large-Cap (b)	2,326				2,326				—			—
Fixed Income:
Common/Collective Trust (a)	11,921				—				11,921			—
Total	$	32,694			$	2,326			$	30,368		$	—
(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	$	7,770			$	3,725
2015	$	8,303			$	3,825
2016	$	8,646			$	3,906
2017	$	9,021			$	3,955
2018	$	10,316			$	3,997
2019 - 2023	$	61,659			$	21,093
Contributions - SJG contributed $9.1 million and $19.8 million to our qualified employee pension plans during the years 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 $1.2 million in 2014 and have been consistent over the past few years. We also have a regulatory obligation to contribute approximately $3.6 million annually to our other postretirement benefit plans’ trusts, less costs incurred directly by us.
Defined Contribution Plan - We also offer an Employees’ Retirement Savings Plan (Savings Plan) to eligible employees. For employees eligible for participation in SJI's defined benefit pension plans, SJG matches 50% of participants’ contributions up to 6% of base compensation. For employees who are not eligible for participation in SJI’s defined benefit plans, we match 50% of participants’ contributions up to 8% of base compensation. Employees not eligible for the pension plans also receive a year-end contribution of $1,000 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 $1.0 million, $0.9 million and $0.8 million for the years ended December 31, 2013, 2012 and 2011, respectively.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	COMMITMENTS AND CONTINGENCIES:
	Standby Letter of Credit - SJG provided a $25.2 million letter of credit under a separate facility outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system.
	Gas Supply Related Contracts - In the normal course of conducting business, we have entered into long-term contracts for natural gas supplies, firm transportation and gas storage service. The earliest date at which any of the primary terms of these contracts expire is October 2014. The transportation and storage agreements entered into between us and each of our interstate pipeline service providers were done so in accordance with their respective FERC approved tariff. Our cumulative obligation for gas supply related demand charges and reservation fees paid for these services averages approximately $4.0 million per month and is recovered on a current basis through the BGSS.
	Pending Litigation - We are subject to claims arising in the ordinary course of business and other legal proceedings. 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 $0.5 million related to all claims in the aggregate, as of both December 31, 2013 and December 31, 2012. 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 60% of our workforce at December 31, 2013. The Company has collective bargaining agreements with two unions who represent these employees: the International Brotherhood of Electrical Workers (IBEW) that operates under a collective bargaining agreement that runs through February 28, 2017. The remaining unionized employees are represented by the International Association of Machinists and Aerospace Workers (IAM). Employees represented by the IAM operate under a collective bargaining agreement that expires in August 2014.
	Environmental Remediation Costs - We incurred and recorded costs for environmental cleanup of 12 sites where we or our predecessors operated gas manufacturing plants. We stopped manufacturing gas in the 1950s.
	We successfully entered into settlements with all of our historic comprehensive general liability carriers regarding the environmental remediation expenditures at our sites. Also, we had purchased a Cleanup Cost Cap Insurance Policy limiting the amount of remediation expenditures that we were required to make at 11 of our sites. This policy provided coverage up to $50.0 million, which was exhausted in 2012.
	Since the early 1980s, we accrued environmental remediation costs of $326.5 million, of which $207.0 million has been spent as of December 31, 2013. The following table details the amounts accrued and expended for environmental remediation at December 31 (in thousands):
		2013			2012
	Beginning of Year	$	107,410		$	89,984
	Accruals	22,264			26,552
	Expenditures	(10,182		)	(9,126		)
	End of Year	$	119,492		$	107,410
	The balances are segregated between current and noncurrent on the balance sheets under the captions Current Liabilities and Regulatory and Other Noncurrent Liabilities.
	Management estimates that undiscounted future costs to clean up our sites will range from $119.5 million to $223.5 million. We recorded the lower end of this range, $119.5 million, as a liability because a single reliable estimation point is not feasible due to the amount of uncertainty involved in the nature of projected remediation efforts and the long period over which remediation efforts will continue. Six of our sites comprise the majority of these estimates, the sum of the six sites range from a low of $100.4 million to a high of $192.8 million. Recorded amounts include estimated costs based on projected investigation and remediation work plans using existing technologies. Actual costs could differ from the estimates due to the long-term nature of the projects, changing technology, government regulations and site-specific requirements. Significant risks surrounding these estimates include unforeseen market price increases for remedial services, property owner acceptance of remedy selection, regulatory approval of selected remedy and remedial investigative findings.
	The remediation efforts at our six most significant sites include the following:
	Site 1 - Several interim remedial actions have been completed at the site. Steps remaining to remediate the balance of the site include 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.

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)	$	8,696	$	8,696	$	—	$	—
	Derivatives – Energy Related Assets (B)	1,500		1,409		91		—
		$	10,196	$	10,105	$	91	$	—
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	759	$	155	$	604	$	—
	Derivatives – Other (C)	3,735		—		3,735		—
		$	4,494	$	155	$	4,339	$	—
	As of December 31, 2012
		Total		Level 1		Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	7,520	$	769	$	6,751	$	—
	Derivatives – Energy Related Assets (B)	766		447		319		—
		$	8,286	$	1,216	$	7,070	$	—
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	2,695	$	2,694	$	1	$	—
	Derivatives – Other (C)	7,761		—		7,761		—
		$	10,456	$	2,694	$	7,762	$	—
	(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. 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, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model.  Market inputs can generally be verified and model selection does not involve significant management judgment.

DERIVATIVE_INSTRUMENTS

DERIVATIVE INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
DERIVATIVE INSTRUMENTS	'
	DERIVATIVE INSTRUMENTS:
	SJG is involved in buying, selling, transporting and storing natural gas and is subject to market risk on expected future purchases and sales due to commodity price fluctuations. The Company, through its affiliate South Jersey Resources Group (SJRG) and another counterparty, uses a variety of derivative instruments to limit this exposure to market risk in accordance with strict corporate guidelines. These derivative instruments include forward contracts, futures contracts, swap agreements and options contracts. As of December 31, 2013, SJG had outstanding derivative contracts intended to limit the exposure to market risk on 6.6 MMdts of expected future purchases of natural gas.. These contracts, which do not qualify for the normal purchase and sale exemption and have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives —Energy Related Assets or Derivatives — Energy Related Liabilities on the balance sheets. The costs or benefits of these short-term contracts are recoverable through SJG’s Basic Gas Supply Service (BGSS) clause, subject to BPU approval. As a result, the net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the balance sheets. As of December 31, 2013 and December 31, 2012, SJG had $0.7 million of unrealized gains and $1.9 million of unrealized losses, respectively, included in its BGSS related to open financial contracts.
	The Company has also entered into interest rate derivatives to manage exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the balance sheets. The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates. Subject to BPU approval, the market value upon termination of these interest rate derivatives can be recovered in rates and therefore these unrealized losses have been included in Regulatory Assets on the balance sheets.
	We previously used derivative transactions known as “Treasury Locks” to mitigate against the impact on our cash flows of possible interest rate increases on debt issued in September 2005.  The initial $1.4 million cost of the Treasury Locks has been included in Accumulated Other Comprehensive Loss and is being amortized over the 30 year life of the associated debt issue.  As of December 31, 2013 and December 31, 2012, the unamortized balance was approximately $1.0 million and $1.1 million, respectively.
	As of December 31, 2013, SJG’s active interest rate swaps were as follows:
	Notional Amount				Fixed Interest Rate			Start Date	Maturity		Type of Debt		Obligor
	$	12,500,000			3.43	%		12/1/06	2/1/36		Tax-exempt		SJG
	$	12,500,000			3.43	%		12/1/06	2/1/36		Tax-exempt		SJG
	The fair values of all derivative instruments, as reflected in the balance sheets as of December 31, 2013 and December 31, 2012, 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		$	1,222			$	711		$	464			$	2,615
	Derivatives – Energy Related – Non-Current		278				48			302				80
	Interest rate contracts:
	Derivatives – Other		—				3,735			—				7,761
	Total derivatives not designated as hedging instruments under GAAP		$	1,500			$	4,494		$	766			$	10,456
	For derivative instruments disclosed in the table above, information as to the presentation on the condensed balance sheets is 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		$	1,500			$	—		$	1,500			$	(155	)	(A)	$	(498	)	$	847
	Derivatives - Energy Related Liabilities		(759		)		—			(759		)		155			(B)	—			(604		)
	Derivatives - Other		(3,735		)		—			(3,735		)		—				—			(3,735		)
	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		$	766			$	—		$	766			$	(447	)	(A)	$	—		$	319
	Derivatives - Energy Related Liabilities		(2,695		)		—			(2,695		)		447			(B)	1,136			(1,112		)
	Derivatives - Other		(7,761		)		—			(7,761		)		—				—			(7,761		)
	(A) The balances at December 31, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at December 31, 2013 and December 31, 2012 were related to derivative assets which can be net settled against derivative liabilities.
	The effect of derivative instruments on the statements of income for 2013 , 2012 and 2011 are as follows (in thousands):
		Year ended December 31,
	Derivatives in Cash Flow Hedging Relationships	2013				2012			2011
	Interest Rate Contracts:
	Losses reclassified from accumulated OCI into income (a)	$	(46	)		$	(46	)	$	(46	)
	(a) 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 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.

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			Total
	Balance at January 1, 2013 (a)	$	(12,958	)	$	(621	)	$	294		$	(13,285	)
	Other comprehensive income before reclassifications	932			—			592			1,524
	Amounts reclassified from AOCL (b)	1,354			27			(489		)	892
	Net current period other comprehensive income	2,286			27			103			2,416
	Balance at December 31, 2013 (a)	$	(10,672	)	$	(594	)	$	397		$	(10,869	)
	(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):
	Components of AOCL	Amounts Reclassified from AOCL			Affected Line Item in the Statements of Income
		For the Year Ended December 31, 2013
	Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	46		Interest Charges
	Unrealized Gain on Available-for-Sale Securities	(828		)	Other Income & Expense
	Actuarial Loss on Postretirement Benefits	2,289			Operating Expenses: Operations
		1,507			Loss (Income) Before Income Taxes
	Income Taxes (a)	615			Income Taxes (a)
	Losses (Gains) from reclassifications for the period net of tax	$	892

QUARTERLY_RESULTS_OF_OPERATION

QUARTERLY RESULTS OF OPERATIONS - UNAUDITED	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
QUARTERLY RESULTS OF OPERATIONS - UNAUDITED	'
	QUARTERLY RESULTS OF OPERATIONS - UNAUDITED:
	The summarized quarterly results of our operations are as follows (in thousands):
		2013 Quarter Ended								2012 Quarter Ended
		31-Mar		30-Jun		Sept. 30		Dec. 31		31-Mar		30-Jun		Sept. 30		Dec. 31
	Operating Revenues	$	174,098	$	66,536	$	59,674	$	146,172	$	179,436	$	59,177	$	54,251	$	129,010
	Expenses:
	Cost of Sales (excluding depreciation)	77,602		26,108		24,717		71,654		86,499		20,407		21,053		60,751
	Operations and Maintenance
	Including Fixed Charges	38,659		33,871		33,249		39,486		35,102		33,597		32,953		33,877
	Income Taxes	20,771		2,269		471		11,322		20,977		1,887		258		10,589
	Energy and Other Taxes	3,003		1,277		1,052		2,530		3,169		1,479		1,167		2,485
	Total Expenses	140,035		63,525		59,489		124,992		145,747		57,370		55,431		107,702
	Other Income and Expense	1,450		810		764		773		1,349		1,430		1,703		(1,865		)
	Net Income	$	35,513	$	3,821	$	949	$	21,953	$	35,038	$	3,237	$	523	$	19,443
	NOTE: Because of the seasonal nature of our business, statements for the 3-month periods are not indicative of the results for a full year.

SUBSEQUENT_EVENT

SUBSEQUENT EVENT	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
SUBSEQUENT EVENT	'
	SUBSEQUENT EVENT:
	In January 2014, SJG issued $30 million aggregate principle amount of 4.23% Medium Term Notes 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 12 months, over the next three years. This petition was approved in January, 2014.

SCHEDULE_II_VALUATION_AND_QUAL

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS (Notes)	12 Months Ended
	Dec. 31, 2013
Valuation and Qualifying Accounts [Abstract]	'
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS	'
	SOUTH JERSEY GAS COMPANY
	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		Charged to Other Accounts -			Deductions -		Balance at End
				Expenses		Describe (a)			Describe (b)		of Period
	Provision for Uncollectible
	Accounts for the Year Ended
	31-Dec-13	$	3,985	$	4,232	$	(41	)	$	3,623	$	4,553
	Provision for Uncollectible
	Accounts for the Year Ended
	31-Dec-12	$	3,060	$	4,775	$	110		$	3,960	$	3,985
	Provision for Uncollectible
	Accounts for the Year Ended
	31-Dec-11	$	4,577	$	1,410	$	562		$	3,489	$	3,060
	(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]	'
The Entity	'
	The Entity - South Jersey Industries, Inc. (SJI) owns all of the outstanding common stock of South Jersey Gas Company (SJG). In our opinion, the financial statements reflect all normal and recurring adjustments needed to fairly present our financial position and operating results at the dates and for the periods presented.
	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 4.
Equity Investments	'
	Equity Investments - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on our balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss.  An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary.
Estimates and Assumptions	'
	Estimates and Assumptions - We prepare our financial statements to conform with accounting principles generally accepted in the United States of America (GAAP). Management makes estimates and assumptions that affect the amounts reported in the financial statements and related disclosures. Therefore, actual results could differ from those estimates. Significant estimates include amounts related to regulatory accounting, energy derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition.
Regulation	'
	Regulation - We are subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 3 for a detailed discussion of our rate structure and regulatory actions. We maintain our accounts according to the BPU’s prescribed Uniform System of Accounts. We follow the accounting for regulated enterprises prescribed by the FASB ASC Topic 980 – “Regulated Operations.”  In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 4 for a detailed discussion of regulatory assets and liabilities.
Operating Revenues	'
	Operating Revenues - Gas revenues are recognized in the period the commodity is delivered to customers. For retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas delivered from the date of the last meter reading to the end of the month.
Revenue and Throughput-Based Taxes	'
	Revenue and Throughput-Based Taxes - We collect certain revenue-based energy taxes from our customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). We also collect 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 Uncollectible Accounts	'
	Accounts Receivable and Provision for Uncollectible Accounts - Accounts receivable are carried at the amount owed by customers. A provision for uncollectible accounts is established based on our collection experience and an assessment of the collectibility of specific accounts.
Natural Gas in Storage	'
	Natural Gas in Storage – Natural Gas in Storage is reflected at average cost on the balance sheets, and represents natural gas that will be utilized in the ordinary course of business.
Property, Plant & Equipment	'
	Property, Plant & Equipment - For regulatory purposes, utility plant is stated at original cost, which may be different than our cost if the assets were acquired from another regulated entity. The cost of adding, replacing and renewing property is charged to the appropriate plant account.
Asset Retirement Obligations	'
	Asset Retirement Obligations - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations we have to cut and cap our gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.
Depreciation	'
	Depreciation - We depreciate utility plant on a straight-line basis over the estimated remaining lives of the various property classes. These estimates are periodically reviewed and adjusted as required after BPU approval. The composite annual rate for all depreciable utility property was approximately 2.3% 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.
Capitalized Interest	'
	Capitalized Interest - We capitalize interest on construction at the rate of return on rate base utilized by the BPU to set rates in our last base rate proceeding (See Note 3). Capitalized interest is included in Utility Plant on the balance sheets. Interest Charges are presented net of capitalized interest on the statements of income.  We capitalized interest of $8.2 million in 2013, $6.5 million in 2012 and $1.1 million in 2011. The increase in 2013 represents the interest on the Company's investment in Utility Plant under the BPU-approved CIRT and AIRP programs. Under the CIRT and AIRP, qualified capital expenditures continued to accrue interest on construction until such projects were rolled into customer rates and recovery of the expenditures commenced.
	All CIRT program investments have been rolled into rate base and the CIRT program is now concluded. See Note 3 for additional discussion of the CIRT programs.
Impairment of Long-Lived Assets	'
	Impairment of Long-Lived Assets - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the years ended 2013, 2012 and 2011, no significant impairments were identified.
Derivative Instruments	'
	Derivative Instruments - SJG, through its affiliate, South Jersey Resources Group (SJRG) and another counterparty, uses a variety of derivative instruments to limit its exposure to market risk in accordance with strict guidelines (See Note 14).  These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives – Energy Related Assets or Derivatives – Energy Related Liabilities on the balance sheets.  The costs or benefits of these short-term contracts are recoverable through SJG’s Basic Gas Supply Service (BGSS) clause, subject to BPU approval.  As a result, the net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the balance sheets.
	SJG has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt.  These interest rate derivatives, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives-Other on the balance sheets.  The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates.  Subject to BPU approval, the market value upon termination of these interest rate derivatives can be recovered in rates and, therefore, these unrealized losses have been included in Other Regulatory Assets in the balance sheets.
Income Taxes	'
	Income Taxes - Deferred income taxes are provided for all significant temporary differences between the book and taxable basis of assets and liabilities in accordance with FASB ASC Topic 740 – “Income Taxes” (See Note 6). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized.
Cash and Cash Equivalents	'
	Cash and Cash Equivalents - For purposes of reporting cash flows, highly liquid investments with original maturities of three months or less are considered cash equivalents.
NEW ACCOUNTING PRONOUNCEMENTS	'
	NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2013, 2012 or 2011 had, or is expected to have, a material impact on the financial statements.
	In January 2012, the FASB issued Accounting Standards Update (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 was 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 was 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. 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, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model.  Market inputs can generally be verified and model selection does not involve significant management judgment.

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Schedule of Utility Plant balances	'
	Utility Plant balances as of December 31, 2013 and 2012 were comprised of the following (in thousands):
		2013			2012
	Utility Plant:
	Production Plant	$	296		$	296
	Storage Plant	22,538			20,316
	Transmission Plant	248,074			250,886
	Distribution Plant	1,417,939			1,297,619
	General Plant	53,162			49,586
	Other Plant	1,855			1,855
	Utility Plant in Service	1,743,864			1,620,558
	Construction Work in Progress	72,940			38,232
	Total Utility Plant	$	1,816,804		$	1,658,790
Asset retirement obligation activity	'
	ARO activity during 2013 and 2012 was as follows (in thousands):
		2013			2012
	ARO as of January 1,	$	38,892		$	29,388
	Accretion	1,514			1,870
	Additions	743			989
	Settlements	(1,630		)	(1,603		)
	Revisions in Estimated Cash Flows *	1,659			8,248
	ARO as of December 31,	$	41,178		$	38,892
	* 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_PLANS_

STOCK-BASED COMPENSATION PLANS (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Summary of the SJI nonvested restricted stock awards pertaining to SJG outstanding at and the assumptions used to estimate the fair value of the awards	'
	The following table summarizes the SJI nonvested restricted stock awards pertaining to SJG outstanding at December 31, 2013, and the assumptions used to estimate the fair value of the awards:
	Grant Date		Shares		Fair Value		Expected		Risk-Free
			Outstanding		Per Share		Volatility		Interest Rate
	Jan. 2012 - TSR		3,533		$	51.23	22.5	%	0.43	%
	Jan. 2012 - EPS		3,533		$	56.93	n/a		n/a
	Jan. 2013 - TSR		4,001		$	44.38	21.1	%	0.4	%
	Jan. 2013 - EPS		4,001		51.18		n/a		n/a
Summary of the information regarding restricted stock award activity excluding accrued dividend equivalents	'
	The following table summarizes information regarding restricted stock award activity during 2013, excluding accrued dividend equivalents:
		Shares		Weighted
				Average
				Grant Date
				Fair Value
	Nonvested Shares Outstanding, January 1, 2013	15,108		$	52.55
	Granted	9,324		$	47.78
	Vested*	(7,116	)	$	50.94
	Cancelled / Forfeited	(2,248	)	$	50.02
	Nonvested Shares Outstanding, December 31, 2013	15,068		$	50.73
	* Performance targets during the 3-year vesting period were not attained for the January 2011 grant. As a result, no shares will be awarded in 2014.

REGULATORY_ASSETS_AND_LIABILIT1

REGULATORY ASSETS AND 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):
		2013		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 at December 31 consisted of the following items (in thousands):
		2013		2012
	Excess Plant Removal Costs	$	40,029	$	45,593
	Deferred Revenue - Net	19,067		10,924
	Other Regulatory Liabilities	1,853		—
	Total Regulatory Liabilities	$	60,949	$	56,517

RELATED_PARTY_TRANSACTIONS_Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Summary of related party transactions	'
	A summary of these related party transactions, excluding pass-through items, included in Operating Revenues were as follows (in thousands):
		2013			2012			2011
	Operating Revenues/Affiliates:
	SJRG	$	1,390		$	884		$	6,532
	Other	1,299			851			716
	Total Operating Revenues/Affiliates	$	2,689		$	1,735		$	7,248
	Related party transactions, excluding pass-through items, included in Operating Expenses were as follows (in thousands):
		2013			2012			2011
	Costs of Sales/Affiliates
	(Excluding depreciation):
	SJRG	$	14,959		$	9,083		$	33,768
	Derivative Losses (See Note 1):
	SJRG	$	887		$	15,407		$	12,872
	Operations Expense/Affiliates:
	SJI	$	11,990		$	10,870		$	9,941
	SJIS	5,531			5,397			4,956
	Millennium	2,686			3,149			3,076
	Other	(428		)	(500		)	(448		)
	Total Operations Expense/Affiliates	$	19,779		$	18,916		$	17,525

INCOME_TAXES_AND_CREDITS_Table

INCOME TAXES AND CREDITS (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of effective income tax rate reconciliation	'
	Total income taxes applicable to operations differ from the tax that would have resulted by applying the statutory Federal income tax rate to pre-tax income for the following reasons (in thousands):
		2013			2012			2011
	Tax at Statutory Rate	$	33,974		$	32,183		$	30,510
	Increase (Decrease) Resulting from:
	State Income Taxes	4,833			5,302			5,316
	Amortization of Investment Tax Credits	(258		)	(287		)	(302		)
	ESOP Dividend	(1,058		)	(1,027		)	(956		)
	AFUDC	(916		)	(1,048		)	(729		)
	Amortization of Flowthrough Depreciation	—			—			526
	Other - Net	(1,742		)	(1,412		)	(84		)
	Net Income Taxes	$	34,833		$	33,711		$	34,281
Schedule of components of provision for income taxes	'
	The provision for Income Taxes is comprised of the following (in thousands):
		2013			2012			2011
	Current:
	Federal	$	(53	)	$	(4,635	)	$	(924	)
	State	2,946			(7		)	168
	Total Current	2,893			(4,642		)	(756		)
	Deferred:
	Federal	27,707			30,477			27,329
	State	4,491			8,163			8,010
	Total Deferred	32,198			38,640			35,339
	Investment Tax Credits	(258		)	(287		)	(302		)
	Net Income Taxes	$	34,833		$	33,711		$	34,281
Schedule of deferred tax assets and liabilities	'
	The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax liabilities at December 31 (in thousands):
		2013			2012
	Current:
	Net Operating Loss Carryforward	$	(27,600	)	$	(2,586	)
	Budget Billing - Customer Accounts	1,152			1,033
	Provision for Uncollectibles	(1,726		)	(1,409		)
	Conservation Incentive Program	4,631			13,942
	Section 461 Prepayments	1,156			930
	Other	(922		)	(1,478		)
	Current Deferred Tax (Asset) Liability - Net	$	(23,309	)	$	10,432
	Noncurrent:
	Book Versus Tax Basis of Property	$	371,684		$	323,470
	Deferred Fuel Costs - Net	1,330			3,325
	Environmental Remediation	14,392			17,643
	Deferred Regulatory Costs	13,665			15,374
	Deferred State Tax	(15,471		)	(15,106		)
	Investment Tax Credit Basis Gross-Up	(185		)	(318		)
	Deferred Pension & Other Post Retirement Benefits	24,218			39,174
	Pension & Other Post Retirement Benefits	(14,152		)	(28,846		)
	Deferred Revenues	(9,266		)	(8,922		)
	Net Operating Loss Carryforward	(8,764		)	(35,901		)
	Other	3,524			464
	Noncurrent Deferred Tax Liability – Net	$	380,975		$	310,357
Reconciliation of unrecognized tax benefits	'
	A reconciliation of unrecognized tax benefits is as follows (in thousands):
		2013			2012			2011
	Balance at January 1,	$	503		$	421		$	478
	Increase as a result of tax position taken in prior years	44			82			119
	Decrease due to a lapse in the statue of limitations	—			—			(90		)
	Settlements	—			—			(86		)
	Balance at December 31,	$	547		$	503		$	421

LONGTERM_DEBT_LONGTERM_DEBT_Ta

LONG-TERM DEBT LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of long-term debt	'
	A schedule of our long-term debt as of December 31, including current maturities, is as follows (in thousands):
				2013			2012
	Long-Term Debt (A):
	First Mortgage Bonds: (B)
	4.46	%	Series due 2013 (C)	$	—		$	10,500
	5.027	%	Series due 2013 (C)	—			14,500
	4.52	%	Series due 2014	11,000			11,000
	5.115	%	Series due 2014	10,000			10,000
	5.387	%	Series due 2015	10,000			10,000
	5.437	%	Series due 2016	10,000			10,000
	4.6	%	Series due 2016	17,000			17,000
	4.657	%	Series due 2017	15,000			15,000
	7.97	%	Series due 2018	10,000			10,000
	7.125	%	Series due 2018	20,000			20,000
	5.587	%	Series due 2019	10,000			10,000
	3	%	Series due 2024	50,000			50,000
	3.03	%	Series due 2024	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 (D)	50,000			—
	3.74	%	Series due 2032	35,000			35,000
	5.55	%	Series due 2033	32,000			32,000
	6.213	%	Series due 2034	10,000			10,000
	5.45	%	Series due 2035	10,000			10,000
	Series A 2006 Tax-Exempt First Mortgage Bonds
	Variable Rate, due 2036 (E)			25,000			25,000
	Total Long-Term Debt Outstanding			475,000			450,000
	Less Current Maturities (A)			(21,000		)	(25,000		)
	Long-Term Debt			$	454,000		$	425,000
	(A)	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $10,909; 2016, $27,909; 2017, $15,909; 2018, $38,909 .Our long-term debt agreements contain no financial covenants.
	(B)	Our First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant.
	(C)	In July 2013, SJG called its $10.5 million, 4.46% Medium Term Notes (MTN) due July 2013 and $14.5 million, 5.027% MTN due September 2013.
	(D)	In November 2013, SJG issued $50.0 million of 4.01% aggregate principal amount of MTN due November 2030.
	(E)	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.

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):
		Total Facility		Usage		Available Liquidity		Expiration Date
	Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	65,500	$	134,500	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total	$	210,000	$	65,500	$	144,500

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											Other Postretirement Benefits
		2013				2012				2011			2013				2012			2011
	Service Cost	$	4,487			$	3,718			$	3,048		$	771			$	704		$	675
	Interest Cost	7,886				8,008				7,828			2,221				2,443			2,621
	Expected Return on Plan Assets	(9,435		)		(8,249		)		(7,415		)	(2,158		)		(1,910		)	(2,040		)
	Amortization:
	Prior Service Cost (Credits)	208				207				219			(195		)		(195		)	(254		)
	Actuarial Loss	7,608				6,432				4,561			1,555				1,534			1,466
	Net Periodic Benefit Cost	10,754				10,116				8,241			2,194				2,576			2,468
	Capitalized Benefit Costs	(5,002		)		(4,684		)		(3,661		)	(1,172		)		(1,340		)	(1,222		)
	Affiliate SERP Allocations	(1,389		)		(1,107		)		(845		)	—				—			—
	Total Net Periodic Benefit Expense	$	4,363			$	4,325			$	3,735		$	1,022			$	1,236		$	1,246
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			$	19,061		$	—
	Amounts Arising during the Period:
	Net Actuarial Loss	11,599				2,089				4,788			—
	Amounts Amortized to Net Periodic Costs:
	Net Actuarial Loss	(4,490		)		(1,535		)		(1,941		)	—
	Prior Service (Cost) Credit	(207		)		195				—			—
	Balance at December 31, 2012	68,713				27,184				21,908			—
	Amounts Arising during the Period:
	Net Actuarial Gain	(20,554		)		(9,171		)		(1,576		)	—
	Amounts Amortized to Net Periodic Costs:
	Net Actuarial Loss	(5,319		)		(1,555		)		(2,289		)	—
	Prior Service (Cost) Credit	(208		)		194				—			—
	Balance at December 31, 2013	$	42,632			$	16,652			$	18,043		$	—
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
	Net Actuarial Loss	$	2,007			$	—
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 our balance sheets follows (in thousands):
										Other
		Pension Benefits								Postretirement Benefits
		2013				2012				2013			2012
	Change in Benefit Obligations:
	Benefit Obligation at Beginning of Year	$	186,899			$	160,319			$	55,615		$	51,656
	Service Cost	4,487				3,718				771			704
	Interest Cost	7,886				8,008				2,221			2,443
	Actuarial (Gain) Loss	(11,514		)		21,990				(4,552		)	4,059
	Retiree Contributions	—				—				335			313
	Plan Amendments	—				—				—			—
	Benefits Paid	(7,090		)		(7,136		)		(3,475		)	(3,560		)
	Benefit Obligation at End of Year	$	180,668			$	186,899			$	50,915		$	55,615
	Change in Plan Assets:
	Fair Value of Plan Assets at Beginning of Year	$	119,391			$	91,738			$	32,694		$	28,942
	Actual Return on Plan Assets	20,049				13,853				5,101			3,880
	Employer Contributions	10,324				20,936				4,816			3,119
	Retiree Contributions	—				—				335			313
	Benefits Paid	(7,090		)		(7,136		)		(3,475		)	(3,560		)
	Fair Value of Plan Assets at End of Year	$	142,674			$	119,391			$	39,471		$	32,694
	Funded Status at End of Year:
	Accrued  Net Benefit Cost at End of Year	$	(37,994	)		$	(67,508	)		$	(11,444	)	$	(22,921	)
	Amounts Recognized in the Statement of Financial Position Consist of:
	Current Liabilities	$	(1,241	)		$	(1,236	)		$	—		$	—
	Noncurrent Liabilities	(36,753		)		(66,272		)		(11,444		)	(22,921		)
	Net Amount Recognized at End of Year	$	(37,994	)		$	(67,508	)		$	(11,444	)	$	(22,921	)
	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
	Net Amount Recognized at End of Year	$	42,632			$	68,713			$	16,652		$	27,184
	Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:
	Net Actuarial Loss	$	18,043			$	21,908			$	—		$	—
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	'
	A one-percentage-point change in assumed health care cost trend rates would have the following effects (in thousands):
		1-Percentage-				1-Percentage-
		Point Increase				Point Decrease
	Effect on the Total of Service and Interest Cost	$	145			$	(115	)
	Effect on Postretirement Benefit Obligation	$	2,406			$	(2,027	)
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets	'
	Fair Value Measurement Using Significant
	Unobservable Inputs (Level 3)
	(In thousands)
		Guaranteed				Hedge				Private			Real				Total
		Insurance				Funds				Equity			Estate
		Contract								Funds
	Balance at January 1, 2012	$	9,647			$	—			$	2,525		$	4,291			$	16,463
	Actual return on plan assets:
	Relating to assets still held at the reporting date	1,082				—				(122		)	487				1,447
	Relating to assets sold during the period	(10		)		—				480			—				470
	Purchases, Sales and Settlements	(821		)		—				(326		)	—				(1,147		)
	Balance at December 31, 2012	$	9,898			$	—			$	2,557		$	4,778			$	17,233
	Actual return on plan assets:
	Relating to assets still held at the reporting date	(68		)		124				80			623				759
	Relating to assets sold during the period	14				—				345			—				359
	Purchases, Sales and Settlements	(773		)		3,204				(542		)	—				1,889
	Balance at December 31, 2013	$	9,071			$	3,328			$	2,440		$	5,401			$	20,240
Schedule of Expected Benefit Payments	'
	Future Benefit Payments - The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following years (in thousands):
		Pension Benefits				Other
						Postretirement Benefits
	2014	$	7,770			$	3,725
	2015	$	8,303			$	3,825
	2016	$	8,646			$	3,906
	2017	$	9,021			$	3,955
	2018	$	10,316			$	3,997
	2019 - 2023	$	61,659			$	21,093
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 SJG’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)	$	334			$	—			$	334		$	—
	STIF-Type Instrument (b)	943				—				943			—
	Equity securities:
	Common/Collective Trust Funds – U.S. (a)	41,527				—				41,527			—
	Common/Collective Trust Funds – International (a)	27,312				—				27,312			—
	U.S. Large-Cap (c)	9,342				9,342				—			—
	U.S. Mid-Cap (c)	3,313				3,313				—			—
	International (c)	2,935				2,935				—			—
	Fixed Income:
	Common/Collective Trust Funds (a)	36,728				—				36,728			—
	Guaranteed Insurance Contract (d)	9,071				—				—			9,071
	Hedge Funds (e)	3,328				—				—			3,328
	Other types of investments:
	Private Equity Fund (f)	2,440				—				—			2,440
	Common/Collective Trust Fund – Real Estate (g)	5,401				—				—			5,401
	Total	$	142,674			$	15,590			$	106,844		$	20,240
	Asset Category	Total				Level 1				Level 2			Level 3
	As of December 31, 2012:
	Cash / Cash Equivalents:
	Common/Collective Trust Funds (a)	$	477			$	—			$	477		$	—
	STIF-Type Instrument (b)	840				—				840			—
	Equity securities:
	Common/Collective Trust Funds – U.S. (a)	33,690				—				33,690			—
	Common/Collective Trust Funds – International (a)	23,448				—				23,448			—
	U.S. Large-Cap (c)	7,126				7,126				—			—
	U.S. Mid-Cap (c)	4,194				4,194				—			—
	U.S. Small-Cap (c)	8				8				—			—
	International (c)	1,462				1,462				—			—
	Fixed Income:
	Common/Collective Trust Funds (a)	30,913				—				30,913			—
	Guaranteed Insurance Contract (d)	9,898				—				—			9,898
	Other types of investments:
	Private Equity Fund (f)	2,557				—				—			2,557
	Common/Collective Trust Fund – Real Estate (g)	4,778				—				—			4,778
	Total	$	119,391			$	12,790			$	89,368		$	17,233
	(a)	This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate).  These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable.  Also included in these funds are interest rate swaps, asset backed securities, mortgage backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments.
	(b)	This category represents short-term investment funds held for the purpose of funding disbursement payment arrangements.  Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information.  Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments.
	(c)	This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy.  These common stocks are actively traded on exchanges and price quotes for these shares are readily available.  These common stocks are classified as Level 1 investments.
	(d)	This category represents SJI’s Group Annuity contracts with a nationally recognized life insurance company.  The contracts are the assets of the plan, while the underlying assets of the contracts are owned by the contract holder.  Valuation is based on a formula and calculation specified within the contract.  Since the valuation is based on the reporting entity’s own assumptions, these contracts are classified as Level 3 investments.
	(e)	This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in the U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments.
	(f)	This category represents a limited partnership which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds.  Fund valuations are reported on a 90 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 2 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 SJG’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)	$	12,412			$	—			$	12,412		$	—
	Common/Collective Trust Funds - International (a)	10,031				—				10,031			—
	Mutual Fund - U.S. Large-Cap (b)	2,814				2,814				—			—
	Fixed Income:
	Common/Collective Trust (a)	14,214				—				14,214			—
	Total	$	39,471			$	2,814			$	36,657		$	—
	Asset Category	Total				Level 1				Level 2			Level 3
	As of December 31, 2012:
	Equity Securities:
	Common/Collective Trust Funds - U.S. (a)	$	9,972			$	—			$	9,972		$	—
	Common/Collective Trust Funds - International (a)	8,475				—				8,475			—
	Mutual Fund - U.S. Large-Cap (b)	2,326				2,326				—			—
	Fixed Income:
	Common/Collective Trust (a)	11,921				—				11,921			—
	Total	$	32,694			$	2,326			$	30,368		$	—
	(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.

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 accrued and expended for environmental remediation at December 31 (in thousands):
		2013			2012
	Beginning of Year	$	107,410		$	89,984
	Accruals	22,264			26,552
	Expenditures	(10,182		)	(9,126		)
	End of Year	$	119,492		$	107,410

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)	$	8,696	$	8,696	$	—	$	—
	Derivatives – Energy Related Assets (B)	1,500		1,409		91		—
		$	10,196	$	10,105	$	91	$	—
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	759	$	155	$	604	$	—
	Derivatives – Other (C)	3,735		—		3,735		—
		$	4,494	$	155	$	4,339	$	—
	As of December 31, 2012
		Total		Level 1		Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	7,520	$	769	$	6,751	$	—
	Derivatives – Energy Related Assets (B)	766		447		319		—
		$	8,286	$	1,216	$	7,070	$	—
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	2,695	$	2,694	$	1	$	—
	Derivatives – Other (C)	7,761		—		7,761		—
		$	10,456	$	2,694	$	7,762	$	—
	(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. 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, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model.  Market inputs can generally be verified and model selection does not involve significant management judgment.

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, SJG’s active interest rate swaps were as follows:
	Notional Amount				Fixed Interest Rate			Start Date	Maturity		Type of Debt		Obligor
	$	12,500,000			3.43	%		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 balance sheets as of December 31, 2013 and December 31, 2012, 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		$	1,222			$	711		$	464			$	2,615
	Derivatives – Energy Related – Non-Current		278				48			302				80
	Interest rate contracts:
	Derivatives – Other		—				3,735			—				7,761
	Total derivatives not designated as hedging instruments under GAAP		$	1,500			$	4,494		$	766			$	10,456
Offsetting arrangements	'
	For derivative instruments disclosed in the table above, information as to the presentation on the condensed balance sheets is 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		$	1,500			$	—		$	1,500			$	(155	)	(A)	$	(498	)	$	847
	Derivatives - Energy Related Liabilities		(759		)		—			(759		)		155			(B)	—			(604		)
	Derivatives - Other		(3,735		)		—			(3,735		)		—				—			(3,735		)
	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		$	766			$	—		$	766			$	(447	)	(A)	$	—		$	319
	Derivatives - Energy Related Liabilities		(2,695		)		—			(2,695		)		447			(B)	1,136			(1,112		)
	Derivatives - Other		(7,761		)		—			(7,761		)		—				—			(7,761		)
	(A) The balances at December 31, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at December 31, 2013 and December 31, 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 statements of income for 2013 , 2012 and 2011 are as follows (in thousands):
		Year ended December 31,
	Derivatives in Cash Flow Hedging Relationships	2013				2012			2011
	Interest Rate Contracts:
	Losses reclassified from accumulated OCI into income (a)	$	(46	)		$	(46	)	$	(46	)
	(a) Included in Interest Charges

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			Total
	Balance at January 1, 2013 (a)	$	(12,958	)	$	(621	)	$	294		$	(13,285	)
	Other comprehensive income before reclassifications	932			—			592			1,524
	Amounts reclassified from AOCL (b)	1,354			27			(489		)	892
	Net current period other comprehensive income	2,286			27			103			2,416
	Balance at December 31, 2013 (a)	$	(10,672	)	$	(594	)	$	397		$	(10,869	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
Reclassifications out of AOCL	'
	The following table provides details about reclassifications out of AOCL for the year ended December 31, 2013 (in thousands):
	Components of AOCL	Amounts Reclassified from AOCL			Affected Line Item in the Statements of Income
		For the Year Ended December 31, 2013
	Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	46		Interest Charges
	Unrealized Gain on Available-for-Sale Securities	(828		)	Other Income & Expense
	Actuarial Loss on Postretirement Benefits	2,289			Operating Expenses: Operations
		1,507			Loss (Income) Before Income Taxes
	Income Taxes (a)	615			Income Taxes (a)
	Losses (Gains) from reclassifications for the period net of tax	$	892

QUARTERLY_RESULTS_OF_OPERATION1

QUARTERLY RESULTS OF OPERATIONS - UNAUDITED (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information	'
	The summarized quarterly results of our operations are as follows (in thousands):
		2013 Quarter Ended								2012 Quarter Ended
		31-Mar		30-Jun		Sept. 30		Dec. 31		31-Mar		30-Jun		Sept. 30		Dec. 31
	Operating Revenues	$	174,098	$	66,536	$	59,674	$	146,172	$	179,436	$	59,177	$	54,251	$	129,010
	Expenses:
	Cost of Sales (excluding depreciation)	77,602		26,108		24,717		71,654		86,499		20,407		21,053		60,751
	Operations and Maintenance
	Including Fixed Charges	38,659		33,871		33,249		39,486		35,102		33,597		32,953		33,877
	Income Taxes	20,771		2,269		471		11,322		20,977		1,887		258		10,589
	Energy and Other Taxes	3,003		1,277		1,052		2,530		3,169		1,479		1,167		2,485
	Total Expenses	140,035		63,525		59,489		124,992		145,747		57,370		55,431		107,702
	Other Income and Expense	1,450		810		764		773		1,349		1,430		1,703		(1,865		)
	Net Income	$	35,513	$	3,821	$	949	$	21,953	$	35,038	$	3,237	$	523	$	19,443

SUMMARY_OF_SIGNIFICANT_ACCOUNT3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Accounting Policies [Abstract]	'		'		'
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%		'
Utility Plant:	'		'		'
Production Plant	296,000		296,000		'
Storage Plant	22,538,000		20,316,000		'
Transmission Plant	248,074,000		250,886,000		'
Distribution Plant	1,417,939,000		1,297,619,000		'
General Plant	53,162,000		49,586,000		'
Other Plant	1,855,000		1,855,000		'
Utility Plant in Service	1,743,864,000		1,620,558,000		'
Construction Work in Progress	72,940,000		38,232,000		'
Total Utility Plant	1,816,804,000		1,658,790,000		'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'		'		'
ARO as of January 1,	38,892,000		29,388,000		'
Accretion	1,514,000		1,870,000		'
Additions	743,000		989,000		'
Settlements	-1,630,000		-1,603,000		'
Revisions in Estimated Cash Flows	1,659,000	[1]	8,248,000	[1]	'
ARO as of December 31,	41,178,000		38,892,000		29,388,000
Composite annual rate for all depreciable utility property	2.30%		2.40%		2.30%
Interest capitalized	$8,200,000		$6,500,000		$1,100,000
[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.B A corresponding increase was made to regulatory assets, thus having no impact on earnings.

STOCKBASED_COMPENSATION_PLANS_1

STOCK-BASED COMPENSATION PLANS (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares Outstanding (in shares)	15,068		15,108	'
Fair Value Per Share (in dollars per share)	$50.73		$52.55	'
Expected volatility, measurement period	'3 years		'	'
Vesting period of shares	'3 years		'3 years	'
Cost of Restricted Stock Awards	$0.40		$0.40	$0.40
Amount capitalized to Utility Plant	0.2		0.2	0.2
Unrecognized compensation cost of awards granted under the plan	0.4		'	'
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	'1 year 8 months 12 days		'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward}	'		'	'
Nonvested Shares Outstanding, beginning balance (in shares)	15,108		'	'
Granted (in shares)	9,324		'	'
Vested (in shares)	-7,116	[1]	'	'
Canceled / Forfeited (in shares)	-2,248		'	'
Nonvested Shares Outstanding, ending balance (in shares)	15,068		15,108	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, beginning balance (in dollars per share)	$52.55		'	'
Weighted Average Grant Date Fair Value, Granted (in dollars per share)	$47.78		'	'
Weighted Average Grant Date Fair Value, Vested (in dollars per share)	$50.94	[1]	'	'
Weighted Average Grant Date Fair Value, Canceled / Forfeited (in dollars per share)	$50.02		'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$50.73		$52.55	'
Number of shares awarded during the period	12,901		7,098	'
Market value of shares awarded	0.6		0.4	'
Cash payments to SJI relating to stock awards	$0.40		$0.30	'
Officers and Key Employees [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Expected to be Granted in Subsequent Year	0		'	'
Grant Date January 2012 - TSR [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares Outstanding (in shares)	3,533		'	'
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)	3,533		'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$51.23		'	'
Grant Date January 2012 - EPS [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares Outstanding (in shares)	3,533		'	'
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)	3,533		'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$56.93		'	'
Grant Date January 2013 - TSR [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares Outstanding (in shares)	4,001		'	'
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)	4,001		'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$44.38		'	'
Grant Date January 2013 - EPS [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Shares Outstanding (in shares)	4,001		'	'
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)	4,001		'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$51.18		'	'
Minimum [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Percentage of actual amount of shares that ultimately vest of original share units granted	0.00%		'	'
Maximum [Member]	'		'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'		'	'
Percentage of actual amount of shares that ultimately vest of original share units granted	150.00%		'	'
[1]	Performance targets during the 3-year vesting period were not attained for the January 2011 grant. As a result, no shares will be awarded in 2014.

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

264 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

31-May-13

Sep. 30, 2012

Jun. 30, 2012

Sep. 30, 2011

Jun. 30, 2011

Jan. 31, 2014

Jan. 31, 2011

Nov. 30, 2010

Jan. 31, 2009

Jul. 31, 2013

Jun. 30, 2013

31-May-13

Jun. 30, 2012

31-May-12

Jun. 30, 2011

Jul. 31, 2013

Jul. 31, 2012

Jul. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Nov. 30, 2012

Aug. 31, 2008

Sep. 30, 2013

Jun. 30, 2013

Sep. 30, 2012

Jun. 30, 2012

Oct. 31, 2011

Jun. 30, 2011

customer

sites

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]

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]

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]

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]

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Environmental Restoration Costs Expended Net [Member]

Environmental Restoration Costs Expended Net [Member]

Schedule of Capitalization [Line Items]

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Public Utilities, Rate of Return on Base Rate

8.21%

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Public Utilities, Return on Common Equity

10.30%

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Public Utilities, Approved Base Rate Increase

$42,100,000

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$16,600,000

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$6,800,000

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$18,700,000

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Public Utilities, Annual Depreciation Reduction Attributable To Petition

1,200,000

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Amount of Regulatory Costs Not yet Approved

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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

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600,000

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27,000,000

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2,200,000

5,800,000

3,100,000

4,700,000

-6,400,000

11,800,000

31,200,000

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

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8.80%

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Amount of Regulatory Costs Approved

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17,800,000

'

2,700,000

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81,300,000

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600,000

'

27,000,000

'

10,600,000

10,600,000

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2,100,000

24,000,000

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5,800,000

'

8,200,000

'

5,400,000

'

Amount of Regulatory Costs Approved, Percent Change in Recoveries

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0.50%

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-8.80%

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-2.90%

-2.90%

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Proceeds from Refunds From Favorable Regulatory Action

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9,400,000

18,700,000

21,100,000

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11,200,000

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Amount of Regulatory Costs Not yet Approved, Prior Year Carryover

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28,000,000

2,500,000

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5,200,000

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

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'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of Regulatory Costs Available Under Program

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Costs, Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of sites for environmental cleanup

'

'

'

'

'

'

'

12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,500,000

41,500,000

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'4 years

'

'

'

'

'

'

Regulatory Costs, Extension Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'6 months

'

'

'

'

'

'

'

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

'

'

'

'

'

47,074

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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_AND_LIABILIT2

REGULATORY ASSETS AND LIABILITIES (Details) (USD $)

12 Months Ended

12 Months Ended

Dec. 31, 2012

Dec. 31, 2013

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 Restoration Costs: Expended - Net [Member]

Environmental Restoration 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 (Note 11) [Member]

Deferred Interest Rate Contracts (Note 11) [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

$352,656,000

$296,081,000

$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_AND_LIABILIT3

REGULATORY ASSETS AND LIABILITIES REGULATORY ASSETS AND LIABILITIES 2 (Details) (USD $)	1 Months Ended
	Sep. 30, 2010	Dec. 31, 2013	Dec. 31, 2012
Regulatory Liabilities [Line Items]	'	'	'
Regulatory Liabilities	'	$60,949,000	$56,517,000
Excess Plant Removal Costs [Member]	'	'	'
Regulatory Liabilities [Line Items]	'	'	'
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]	'	'	'
Regulatory Liabilities	'	19,067,000	10,924,000
Other Regulatory Liabilities [Member]	'	'	'
Regulatory Liabilities [Line Items]	'	'	'
Regulatory Liabilities	'	$1,853,000	$0

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Revenues [Abstract]	'	'	'
Operating Revenues	$2,689	$1,735	$7,248
Energy-Related Derivative Losses	400	15,400	12,900
Operating Expenses [Abstract]	'	'	'
Operating Expenses	19,779	18,916	17,525
SJRG [Member]	'	'	'
Operating Revenues [Abstract]	'	'	'
Operating Revenues	1,390	884	6,532
Cost of Sales	14,959	9,083	33,768
Energy-Related Derivative Losses	887	15,407	12,872
SJI [Member]	'	'	'
Operating Expenses [Abstract]	'	'	'
Operating Expenses	11,990	10,870	9,941
SJIS [Member]	'	'	'
Operating Expenses [Abstract]	'	'	'
Operating Expenses	5,531	5,397	4,956
Millennium [Member]	'	'	'
Operating Expenses [Abstract]	'	'	'
Operating Expenses	2,686	3,149	3,076
Other [Member]	'	'	'
Operating Revenues [Abstract]	'	'	'
Operating Revenues	1,299	851	716
Operating Expenses [Abstract]	'	'	'
Operating Expenses	($428)	($500)	($448)

INCOME_TAXES_AND_CREDITS_Detai

INCOME TAXES AND CREDITS (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	'	'	'	'	'	'	'	'	$33,974,000	$32,183,000	$30,510,000
Increase (Decrease) Resulting from:	'	'	'	'	'	'	'	'	'	'	'
State Income Taxes	'	'	'	'	'	'	'	'	4,833,000	5,302,000	5,316,000
Amortization of Investment Tax Credits	'	'	'	'	'	'	'	'	-258,000	-287,000	-302,000
ESOP Dividend	'	'	'	'	'	'	'	'	-1,058,000	-1,027,000	-956,000
AFUDC	'	'	'	'	'	'	'	'	-916,000	-1,048,000	-729,000
Amortization of Flowthrough Depreciation	'	'	'	'	'	'	'	'	0	0	526,000
Other - Net	'	'	'	'	'	'	'	'	-1,742,000	-1,412,000	-84,000
Net Income Taxes	11,322,000	471,000	2,269,000	20,771,000	10,589,000	258,000	1,887,000	20,977,000	34,833,000	33,711,000	34,281,000
Current:	'	'	'	'	'	'	'	'	'	'	'
Federal	'	'	'	'	'	'	'	'	-53,000	-4,635,000	-924,000
State	'	'	'	'	'	'	'	'	2,946,000	-7,000	168,000
Total Current	'	'	'	'	'	'	'	'	2,893,000	-4,642,000	-756,000
Deferred:	'	'	'	'	'	'	'	'	'	'	'
Federal	'	'	'	'	'	'	'	'	27,707,000	30,477,000	27,329,000
State	'	'	'	'	'	'	'	'	4,491,000	8,163,000	8,010,000
Total Deferred	'	'	'	'	'	'	'	'	32,198,000	38,640,000	35,339,000
Investment Tax Credits	'	'	'	'	'	'	'	'	-258,000	-287,000	-302,000
Net Income Taxes	11,322,000	471,000	2,269,000	20,771,000	10,589,000	258,000	1,887,000	20,977,000	34,833,000	33,711,000	34,281,000
Annual amortization rate of investment tax credits	'	'	'	'	'	'	'	'	3.00%	'	'
Current:	'	'	'	'	'	'	'	'	'	'	'
Current Deferred Tax (Asset) Liability - Net	-23,309,000	'	'	'	10,432,000	'	'	'	-23,309,000	10,432,000	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Noncurrent Deferred Tax Liability b Net	380,975,000	'	'	'	310,357,000	'	'	'	380,975,000	310,357,000	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'	'	'	'	'	'	'	'	'	'	'
Balance at January 1,	'	'	'	503,000	'	'	'	421,000	503,000	421,000	478,000
Increase as a result of tax position taken in prior years	'	'	'	'	'	'	'	'	44,000	82,000	119,000
Decrease due to a lapse in the statue of limitations	'	'	'	'	'	'	'	'	0	0	-90,000
Settlements	'	'	'	'	'	'	'	'	0	0	-86,000
Balance at December 31,	547,000	'	'	'	503,000	'	'	'	547,000	503,000	421,000
Accrued interest and penalties on unrecognized tax benefits	600,000	'	'	'	600,000	'	'	'	600,000	600,000	600,000
Internal Revenue Service (IRS) [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	103,700,000	'	'	'	'	'	'	'	103,700,000	'	'
Internal Revenue Service (IRS) [Member] | 2031 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	99,400,000	'	'	'	'	'	'	'	99,400,000	'	'
Internal Revenue Service (IRS) [Member] | 2032 [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Operating loss carryforwards	4,300,000	'	'	'	'	'	'	'	4,300,000	'	'
SJI [Member] | Prepaid Taxes [Member]	'	'	'	'	'	'	'	'	'	'	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Income taxes due from parent company	0	'	'	'	4,600,000	'	'	'	0	4,600,000	'
Classified as Current [Member]	'	'	'	'	'	'	'	'	'	'	'
Current:	'	'	'	'	'	'	'	'	'	'	'
Net Operating Loss Carryforward	-27,600,000	'	'	'	-2,586,000	'	'	'	-27,600,000	-2,586,000	'
Budget Billing - Customer Accounts	1,152,000	'	'	'	1,033,000	'	'	'	1,152,000	1,033,000	'
Provision for Uncollectibles	-1,726,000	'	'	'	-1,409,000	'	'	'	-1,726,000	-1,409,000	'
Conservation Incentive Program	4,631,000	'	'	'	13,942,000	'	'	'	4,631,000	13,942,000	'
Section 461 Prepayments	1,156,000	'	'	'	930,000	'	'	'	1,156,000	930,000	'
Other	-922,000	'	'	'	-1,478,000	'	'	'	-922,000	-1,478,000	'
Classified as Noncurrent [Member]	'	'	'	'	'	'	'	'	'	'	'
Current:	'	'	'	'	'	'	'	'	'	'	'
Net Operating Loss Carryforward	-8,764,000	'	'	'	-35,901,000	'	'	'	-8,764,000	-35,901,000	'
Noncurrent:	'	'	'	'	'	'	'	'	'	'	'
Book Versus Tax Basis of Property	371,684,000	'	'	'	323,470,000	'	'	'	371,684,000	323,470,000	'
Deferred Fuel Costs - Net	1,330,000	'	'	'	3,325,000	'	'	'	1,330,000	3,325,000	'
Environmental Remediation	14,392,000	'	'	'	17,643,000	'	'	'	14,392,000	17,643,000	'
Deferred Regulatory Costs	13,665,000	'	'	'	15,374,000	'	'	'	13,665,000	15,374,000	'
Deferred State Tax	-15,471,000	'	'	'	-15,106,000	'	'	'	-15,471,000	-15,106,000	'
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	-14,152,000	'	'	'	-28,846,000	'	'	'	-14,152,000	-28,846,000	'
Deferred Revenues	-9,266,000	'	'	'	-8,922,000	'	'	'	-9,266,000	-8,922,000	'
Other	$3,524,000	'	'	'	$464,000	'	'	'	$3,524,000	$464,000	'

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Jan. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jul. 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, 2013

Dec. 31, 2011

Jul. 31, 2013

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]

Bonds at variable rates [Member]

Bonds at variable rates [Member]

Bonds at variable rates [Member]

Medium-term Notes [Member]

Medium-term Notes [Member]

Medium-term Notes [Member]

Subsequent Event [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 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, 4.60% [Member]

Series Due 2016, 4.60% [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, 3.03% [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 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 Due 2013, 4.46% [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

Stated interest rate

'

'

4.23%

4.46%

'

5.03%

5.03%

'

4.52%

'

5.12%

'

5.39%

'

5.44%

'

4.60%

'

4.66%

'

7.97%

'

7.13%

'

5.59%

'

3.00%

'

3.03%

'

3.63%

'

4.84%

'

4.93%

'

4.03%

'

4.01%

'

3.74%

'

5.55%

'

6.21%

'

5.45%

'

'

'

'

'

'

4.46%

Total Long-Term Debt Outstanding

$475,000,000

[1]

$450,000,000

[1]

'

$0

[1],[2],[3]

$10,500,000

[1],[2],[3]

$0

[1],[2],[3]

$14,500,000

$14,500,000

[1],[2],[3]

$11,000,000

[1],[3]

$11,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$17,000,000

[1],[3]

$17,000,000

[1],[3]

$15,000,000

[1],[3]

$15,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$20,000,000

[1],[3]

$20,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$50,000,000

[1],[3]

$50,000,000

[1],[3]

$35,000,000

[1],[3]

$35,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$15,000,000

[1],[3]

$15,000,000

[1],[3]

$45,000,000

[1],[3]

$45,000,000

[1],[3]

$45,000,000

[1],[3]

$45,000,000

[1],[3]

$50,000,000

[1],[3],[4]

$0

[1],[3],[4]

$35,000,000

[1],[3]

$35,000,000

[1],[3]

$32,000,000

[1],[3]

$32,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$10,000,000

[1],[3]

$25,000,000

[1],[5]

$25,000,000

[1],[5]

'

'

'

'

Less Current Maturities

-21,000,000

[1]

-25,000,000

[1]

'

'

'

'

'

'

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'

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'

'

'

Long-Term Debt

454,000,000

[1]

425,000,000

[1]

'

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'

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'

'

Long-term Debt, Fiscal Year Maturity [Abstract]

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2014

21,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2015

10,909,000

'

'

'

'

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'

'

'

'

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'

'

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'

'

'

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'

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'

'

'

'

'

'

'

'

2016

27,909,000

'

'

'

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'

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'

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'

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'

'

'

'

'

'

2017

15,909,000

'

'

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'

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'

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'

'

'

'

'

'

'

'

2018

38,909,000

'

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'

'

Extinguishment of Debt, Amount

'

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'

'

10,500,000

Interest rate at end of period

'

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0.07%

'

'

'

Approved borrowing capacity

'

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'

'

200,000,000

'

Available borrowing capacity

'

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'

'

30,000,000

'

'

Debt Instrument, Face Amount

'

'

$30,000,000

'

'

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'

'

[1]

Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $10,909; 2016, $27,909; 2017, $15,909; 2018, $38,909 .Our long-term debt agreements contain no financial covenants.

[2]

In July 2013, SJG called its $10.5 million, 4.46% Medium Term Notes (MTN) due July 2013 and $14.5 million, 5.027% MTN due September 2013.

[3]

Our First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant.

[4]

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

[5]

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.

FINANCIAL_INSTRUMENTS_Details

FINANCIAL INSTRUMENTS (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012
Schedule of Financial Instruments [Line Items]	'		'
Term	'5 years		'
Carrying amount of long-term debt	$475,000,000	[1]	$450,000,000	[1]
Fair Value, Inputs, Level 1 [Member]	'		'
Schedule of Financial Instruments [Line Items]	'		'
Restricted investments held in escrow	100,000		100,000
Margin accounts with selected counterparties to support risk management activities	500,000		1,100,000
Fair Value, Inputs, Level 2 [Member]	'		'
Schedule of Financial Instruments [Line Items]	'		'
Estimated fair value of long-term debt	486,500,000		502,000,000
Carrying amount of long-term debt	475,000,000		450,000,000
Fair Value, Inputs, Level 2 [Member] | Financing Receivable [Member]	'		'
Schedule of Financial Instruments [Line Items]	'		'
Long-term receivables, net of unamortized discount	15,000,000		13,600,000
Imputed interest on long term receivables	$1,300,000		$1,300,000
[1]	Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $10,909; 2016, $27,909; 2017, $15,909; 2018, $38,909 .Our long-term debt agreements contain no financial covenants.

LINES_OF_CREDIT_Details

LINES OF CREDIT (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Line of Credit Facility [Line Items]	'	'	'
Total Facility	$210,000,000	'	'
Usage	65,500,000	'	'
Available Liquidity	144,500,000	'	'
Average borrowings outstanding during the period	91,400,000	142,400,000	'
Maximum amounts outstanding during the period	121,900,000	180,500,000	'
Weighted average borrowing cost	0.37%	0.48%	0.62%
Minimum [Member]	'	'	'
Line of Credit Facility [Line Items]	'	'	'
Financial covenant, ratio of indebtedness to consolidated total capitalization minimum	0.65	'	'
Revolving Credit Facility [Member]	'	'	'
Line of Credit Facility [Line Items]	'	'	'
Total Facility	200,000,000	'	'
Usage	65,500,000	'	'
Available Liquidity	134,500,000	'	'
Expiration Date	'May 2018	'	'
Uncommitted Bank Lines [Member]	'	'	'
Line of Credit Facility [Line Items]	'	'	'
Total Facility	10,000,000	'	'
Usage	0	'	'
Available Liquidity	10,000,000	'	'
Expiration Date	'August 2014	'	'
South Jersey Gas Commercial Paper Program [Member]	'	'	'
Line of Credit Facility [Line Items]	'	'	'
Total Facility	$200,000,000	'	'
Fixed maturities of notes, at maximum number of days (in days)	'270 days	'	'

RETAINED_EARNINGS_Details

RETAINED EARNINGS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Equity [Abstract]	'	'	'
Equity infusions from SJI	$25,000	$0	$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	$4,487	$3,718	$3,048
Interest Cost	7,886	8,008	7,828
Expected Return on Plan Assets	-9,435	-8,249	-7,415
Amortizations [Abstract]	'	'	'
Prior Service Cost (Credits)	208	207	219
Actuarial Loss	7,608	6,432	4,561
Net Periodic Benefit Cost	10,754	10,116	8,241
Capitalized Benefit Costs	-5,002	-4,684	-3,661
Affiliate SERP Allocations	-1,389	-1,107	-845
Total Net Periodic Benefit Expense	4,363	4,325	3,735
Other Postretirement Benefits [Member]	'	'	'
Net periodic benefit cost [Abstract]	'	'	'
Service Cost	771	704	675
Interest Cost	2,221	2,443	2,621
Expected Return on Plan Assets	-2,158	-1,910	-2,040
Amortizations [Abstract]	'	'	'
Prior Service Cost (Credits)	-195	-195	-254
Actuarial Loss	1,555	1,534	1,466
Net Periodic Benefit Cost	2,194	2,576	2,468
Capitalized Benefit Costs	-1,172	-1,340	-1,222
Affiliate SERP Allocations	0	0	0
Total Net Periodic Benefit Expense	$1,022	$1,236	$1,246

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 Gain (Loss)	-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	21,908	19,061
Amounts Arising During the Period, Net Actuarial Gain (Loss)	-1,576	4,788
Amounts Amortized to Net Periodic Costs, Net Actuarial Loss	-2,289	-1,941
Amounts Amortized to Net Periodic Costs, Prior Service (Cost) Credit	0	0
Ending Balance	18,043	21,908
Other Postretirement Benefits [Member]	'	'
Regulatory Assets	'	'
Beginning Balance	27,184	26,435
Amounts Arising During the Period, Net Actuarial Gain (Loss)	-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	0	0
Amounts Arising During the Period, Net Actuarial Gain (Loss)	0	0
Amounts Amortized to Net Periodic Costs, Net Actuarial Loss	0	0
Amounts Amortized to Net Periodic Costs, Prior Service (Cost) Credit	0	0
Ending Balance	$0	$0

PENSION_AND_OTHER_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	$158
Net Actuarial Loss	2,856
Net Actuarial Loss	2,007
Other Postretirement Benefits [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Prior Service Costs	133
Net Actuarial Loss	790
Net Actuarial Loss	$0

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	($1,241,000)	($1,236,000)	'
Noncurrent Liabilities	-48,197,000	-89,193,000	'
Pension Benefits [Member]	'	'	'
Change in Benefit Obligations:	'	'	'
Benefit Obligation at Beginning of Year	186,899,000	160,319,000	'
Service Cost	4,487,000	3,718,000	3,048,000
Interest Cost	7,886,000	8,008,000	7,828,000
Actuarial (Gain) Loss	-11,514,000	21,990,000	'
Retiree Contributions	0	0	'
Plan Amendments	0	0	'
Benefits Paid	-7,090,000	-7,136,000	'
Benefit Obligation at End of Year	180,668,000	186,899,000	160,319,000
Change in Plan Assets:	'	'	'
Fair Value of Plan Assets at Beginning of Year	119,391,000	91,738,000	'
Actual Return on Plan Assets	20,049,000	13,853,000	'
Employer Contributions	10,324,000	20,936,000	'
Retiree Contributions	0	0	'
Benefits Paid	-7,090,000	-7,136,000	'
Fair Value of Plan Assets at End of Year	142,674,000	119,391,000	91,738,000
Amounts Recognized in the Statement of Financial Position Consist of:	'	'	'
Current Liabilities	-1,241,000	-1,236,000	'
Noncurrent Liabilities	-36,753,000	-66,272,000	'
Net Amount Recognized at End of Year	-37,994,000	-67,508,000	'
Amounts Recognized in Regulatory Assets Consist of:	'	'	'
Prior Service Costs	634,000	842,000	'
Net Actuarial Loss	41,998,000	67,871,000	'
Net Amount Recognized at End of Year	42,632,000	68,713,000	61,811,000
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:	'	'	'
Net Actuarial Loss	18,043,000	21,908,000	'
Projected benefit obligation	143,500,000	149,500,000	'
Accumulated benefit obligation	131,400,000	135,600,000	'
Other Postretirement Benefits [Member]	'	'	'
Change in Benefit Obligations:	'	'	'
Benefit Obligation at Beginning of Year	55,615,000	51,656,000	'
Service Cost	771,000	704,000	675,000
Interest Cost	2,221,000	2,443,000	2,621,000
Actuarial (Gain) Loss	-4,552,000	4,059,000	'
Retiree Contributions	335,000	313,000	'
Plan Amendments	0	0	'
Benefits Paid	-3,475,000	-3,560,000	'
Benefit Obligation at End of Year	50,915,000	55,615,000	51,656,000
Change in Plan Assets:	'	'	'
Fair Value of Plan Assets at Beginning of Year	32,694,000	28,942,000	'
Actual Return on Plan Assets	5,101,000	3,880,000	'
Employer Contributions	4,816,000	3,119,000	'
Retiree Contributions	335,000	313,000	'
Benefits Paid	-3,475,000	-3,560,000	'
Fair Value of Plan Assets at End of Year	39,471,000	32,694,000	28,942,000
Amounts Recognized in the Statement of Financial Position Consist of:	'	'	'
Current Liabilities	0	0	'
Noncurrent Liabilities	-11,444,000	-22,921,000	'
Net Amount Recognized at End of Year	-11,444,000	-22,921,000	'
Amounts Recognized in Regulatory Assets Consist of:	'	'	'
Prior Service Costs	952,000	758,000	'
Net Actuarial Loss	15,700,000	26,426,000	'
Net Amount Recognized at End of Year	16,652,000	27,184,000	26,435,000
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:	'	'	'
Net Actuarial Loss	0	0	'
Supplemental Employee Retirement Plans, Defined Benefit [Member]	'	'	'
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of:	'	'	'
Projected benefit obligation	37,200,000	37,400,000	'
Accumulated benefit obligation	36,200,000	35,700,000	'
SJI [Member] | Pension Benefits [Member]	'	'	'
Funded Status at End of Year:	'	'	'
Accrued Net Benefit Cost at End of Year	-37,994,000	-67,508,000	'
SJI [Member] | Other Postretirement Benefits [Member]	'	'	'
Funded Status at End of Year:	'	'	'
Accrued Net Benefit Cost at End of Year	($11,444,000)	($22,921,000)	'

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) (Other Postretirement Benefits [Member])	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Other Postretirement Benefits [Member]	'	'
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	$145
1 - Percentage Point Increase, Effect on Postretirement Benefit Obligation	2,406
1 - Percentage Point Decrease, Effect on the Total of Service and Interest Cost	-115
1 - Percentage Point Decrease, Effect on Postretirement Benefit Obligation	($2,027)

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	28.00%
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Maximum	48.00%
Equity Securities, International Securities [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Minimum	13.00%
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Maximum	25.00%
Fixed Income Securities [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Minimum	32.00%
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Maximum	42.00%
Other Investments [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Minimum	2.00%
Defined Benefit Plan, Target Allocation Percentage of Assets, Equity Securities, Range Maximum	14.00%

Recovered_Sheet1

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

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, 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, 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, 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, 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, 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, 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, 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]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

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

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

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Small-Cap [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [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]

Hedge Funds [Member]

Private Equity Fund [Member]

Private Equity Fund [Member]

Common/Collective Trust Fund b Real Estate [Member]

Common/Collective Trust Fund b Real Estate [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

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

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

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

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

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust [Member]

Common/Collective Trust [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [Member]

Level 3 [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]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

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

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

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Small-Cap [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [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]

Hedge Funds [Member]

Private Equity Fund [Member]

Private Equity Fund [Member]

Common/Collective Trust Fund b Real Estate [Member]

Common/Collective Trust Fund b Real Estate [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

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

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

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Small-Cap [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [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]

Hedge Funds [Member]

Private Equity Fund [Member]

Private Equity Fund [Member]

Common/Collective Trust Fund b Real Estate [Member]

Common/Collective Trust Fund b Real Estate [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

STIF-Type Instrument [Member]

STIF-Type Instrument [Member]

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

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

U.S. Large-Cap [Member]

U.S. Large-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Mid-Cap [Member]

U.S. Small-Cap [Member]

Equity Securities, International Securities [Member]

Equity Securities, International Securities [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]

Hedge Funds [Member]

Hedge Funds [Member]

Private Equity Fund [Member]

Private Equity Fund [Member]

Common/Collective Trust Fund b Real Estate [Member]

Common/Collective Trust Fund b Real Estate [Member]

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

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

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

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

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust [Member]

Common/Collective Trust [Member]

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

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

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

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

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust [Member]

Common/Collective Trust [Member]

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

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

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

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

Common/Collective Trust Funds [Member]

Common/Collective Trust Funds [Member]

Common/Collective Trust [Member]

Common/Collective Trust [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]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

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'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

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'

'

'

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'

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'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Plan Assets

$142,674

$91,738

$334

[1]

$477

[1]

$943

[2]

$840

[2]

$41,527

[1]

$33,690

[1]

$9,342

[3]

$7,126

[3]

$3,313

[3]

$4,194

[3]

$8

[3]

$2,935

[3]

$1,462

[3]

$27,312

[1]

$23,448

[1]

$36,728

[1]

$30,913

[1]

$9,071

[4]

$9,898

[4]

$3,328

[5]

$2,440

[6]

$2,557

[6]

$5,401

[7]

$4,778

[7]

$15,590

$12,790

$0

[1]

$0

[1]

$0

[2]

$0

[2]

$0

[1]

$0

[1]

$9,342

[3]

$7,126

[3]

$3,313

[3]

$4,194

[3]

$8

[3]

$2,935

[3]

$1,462

[3]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

$0

[4]

$0

[4]

$0

[5]

$0

[6]

$0

[6]

$0

[7]

$0

[7]

$106,844

$89,368

$334

[1]

$477

[1]

$943

[2]

$840

[2]

$41,527

[1]

$33,690

[1]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$27,312

[1]

$23,448

[1]

$36,728

[1]

$30,913

[1]

$0

[4]

$0

[4]

$0

[5]

$0

[6]

$0

[6]

$0

[7]

$0

[7]

$20,240

$17,233

$0

[1]

$0

[1]

$0

[2]

$0

[2]

$0

[1]

$0

[1]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

$9,071

[4]

$9,898

[4]

$3,328

[5]

$0

$2,440

[6]

$2,557

[6]

$5,401

[7]

$4,778

[7]

$39,471

$32,694

$28,942

$12,412

[1]

$9,972

[1]

$2,814

[8]

$2,326

[8]

$10,031

[1]

$8,475

[1]

$14,214

[1]

$11,921

[1]

$2,814

$2,326

$0

[1]

$0

[1]

$2,814

[8]

$2,326

[8]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

$36,657

$30,368

$12,412

[1]

$9,972

[1]

$0

[8]

$0

[8]

$10,031

[1]

$8,475

[1]

$14,214

[1]

$11,921

[1]

$0

$0

$0

[1]

$0

[1]

$0

[8]

$0

[8]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

'

'

'

'

'

'

Fund Valuations Lag Period

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

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'

'

'

'

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'

'

'

'

'

'

'

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'

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'

'

'

'

'

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'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

'

'

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'

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'

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'

'

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'

'

'

'

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'

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'

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'

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'

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'

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'

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'

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'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

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'

'

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'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Plan Assets at Beginning of Year

119,391

91,738

334

[1]

477

[1]

943

[2]

840

[2]

41,527

[1]

33,690

[1]

9,342

[3]

7,126

[3]

3,313

[3]

4,194

[3]

8

[3]

2,935

[3]

1,462

[3]

27,312

[1]

23,448

[1]

36,728

[1]

30,913

[1]

9,071

[4]

9,898

[4]

3,328

[5]

2,440

[6]

2,557

[6]

5,401

[7]

4,778

[7]

15,590

12,790

0

[1]

0

[1]

0

[2]

0

[2]

0

[1]

0

[1]

9,342

[3]

7,126

[3]

3,313

[3]

4,194

[3]

8

[3]

2,935

[3]

1,462

[3]

0

[1]

0

[1]

0

[1]

0

[1]

0

[4]

0

[4]

0

[5]

0

[6]

0

[6]

0

[7]

0

[7]

106,844

89,368

334

[1]

477

[1]

943

[2]

840

[2]

41,527

[1]

33,690

[1]

0

[3]

0

[3]

0

[3]

0

[3]

0

[3]

0

[3]

0

[3]

27,312

[1]

23,448

[1]

36,728

[1]

30,913

[1]

0

[4]

0

[4]

0

[5]

0

[6]

0

[6]

0

[7]

0

[7]

17,233

16,463

0

[1]

0

[1]

0

[2]

0

[2]

0

[1]

0

[1]

0

[3]

0

[3]

0

[3]

0

[3]

0

[3]

0

[3]

0

[3]

0

[1]

0

[1]

0

[1]

0

[1]

9,898

[4]

9,647

0

0

2,557

[6]

2,525

4,778

[7]

4,291

39,471

32,694

28,942

12,412

[1]

9,972

[1]

2,814

[8]

2,326

[8]

10,031

[1]

8,475

[1]

14,214

[1]

11,921

[1]

2,814

2,326

0

[1]

0

[1]

2,814

[8]

2,326

[8]

0

[1]

0

[1]

0

[1]

0

[1]

36,657

30,368

12,412

[1]

9,972

[1]

0

[8]

0

[8]

10,031

[1]

8,475

[1]

14,214

[1]

11,921

[1]

0

0

0

[1]

0

[1]

0

[8]

0

[8]

0

[1]

0

[1]

0

[1]

0

[1]

'

'

'

'

'

'

Actual return on plan assets [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Relating to assets still held at the reporting date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

759

1,447

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-68

1,082

124

0

80

-122

623

487

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Relating to assets sold during the period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

359

470

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

14

-10

0

0

345

480

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchases, Sales, and Settlements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,889

-1,147

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-773

-821

3,204

0

-542

-326

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value of Plan Assets at End of Year

$142,674

$91,738

$334

[1]

$477

[1]

$943

[2]

$840

[2]

$41,527

[1]

$33,690

[1]

$9,342

[3]

$7,126

[3]

$3,313

[3]

$4,194

[3]

$8

[3]

$2,935

[3]

$1,462

[3]

$27,312

[1]

$23,448

[1]

$36,728

[1]

$30,913

[1]

$9,071

[4]

$9,898

[4]

$3,328

[5]

$2,440

[6]

$2,557

[6]

$5,401

[7]

$4,778

[7]

$15,590

$12,790

$0

[1]

$0

[1]

$0

[2]

$0

[2]

$0

[1]

$0

[1]

$9,342

[3]

$7,126

[3]

$3,313

[3]

$4,194

[3]

$8

[3]

$2,935

[3]

$1,462

[3]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

$0

[4]

$0

[4]

$0

[5]

$0

[6]

$0

[6]

$0

[7]

$0

[7]

$106,844

$89,368

$334

[1]

$477

[1]

$943

[2]

$840

[2]

$41,527

[1]

$33,690

[1]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$27,312

[1]

$23,448

[1]

$36,728

[1]

$30,913

[1]

$0

[4]

$0

[4]

$0

[5]

$0

[6]

$0

[6]

$0

[7]

$0

[7]

$20,240

$17,233

$0

[1]

$0

[1]

$0

[2]

$0

[2]

$0

[1]

$0

[1]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[3]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

$9,071

[4]

$9,898

[4]

$3,328

[5]

$0

$2,440

[6]

$2,557

[6]

$5,401

[7]

$4,778

[7]

$39,471

$32,694

$28,942

$12,412

[1]

$9,972

[1]

$2,814

[8]

$2,326

[8]

$10,031

[1]

$8,475

[1]

$14,214

[1]

$11,921

[1]

$2,814

$2,326

$0

[1]

$0

[1]

$2,814

[8]

$2,326

[8]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

$36,657

$30,368

$12,412

[1]

$9,972

[1]

$0

[8]

$0

[8]

$10,031

[1]

$8,475

[1]

$14,214

[1]

$11,921

[1]

$0

$0

$0

[1]

$0

[1]

$0

[8]

$0

[8]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

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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 assetsB 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 funds held for the purpose of funding disbursement payment arrangements. Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information. Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments.

[3]

This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy. These common stocks are actively traded on exchanges and price quotes for these shares are readily available. These common stocks are classified as Level 1 investments.

[4]

This category represents SJIbs 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 entitybs own assumptions, these contracts are classified as Level 3 investments.

[5]

This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in the U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments.

[6]

This category represents a limited partnership which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 day lag and, therefore, the value reported herein represents the market value as of September 30, 2013 and 2012, respectively. The fundbs 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 2 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	$9,100,000	$19,757,000	$0
Pension Benefits [Member]	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'
2014	7,770,000	'	'
2015	8,303,000	'	'
2016	8,646,000	'	'
2017	9,021,000	'	'
2018	10,316,000	'	'
2019- 2023	61,659,000	'	'
Pension Contributions	9,100,000	19,800,000	'
Other Postretirement Benefits [Member]	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'
2014	3,725,000	'	'
2015	3,825,000	'	'
2016	3,906,000	'	'
2017	3,955,000	'	'
2018	3,997,000	'	'
2019- 2023	21,093,000	'	'
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	$1,200,000	'	'

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	$0.90	$0.80
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	'	'
Years of Service Threshold to Determine Year End Contribution	'10 years	'	'
Year End Contribution for Employees With More Then Ten Years of Service	1,500	'	'

COMMITMENTS_AND_CONTINGENCIES_1

COMMITMENTS AND CONTINGENCIES (Details) (USD $)	12 Months Ended		408 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
	unions	sites	unions
	sites
Loss Contingencies [Line Items]	'	'	'
Letter of credit provided	$210,000,000	'	$210,000,000
Monthly gas supply related demand charges and reservation fees	4,000,000	'	'
Estimated litigation liability	500,000	500,000	500,000
Percentage of personnel represented in collective bargaining agreements	60.00%	'	60.00%
Number of unions	2	'	2
Number of sites for environmental cleanup	'	12	'
Number of sites covered by insurance	'	11	'
Insurance policy limit	'	50,000,000	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Beginning of Year	107,410,000	89,984,000	'
Accruals	22,264,000	26,552,000	326,500,000
Expenditures	-10,182,000	-9,126,000	-207,000,000
End of Year	119,492,000	107,410,000	119,492,000
Standby Letter of Credit [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Letter of credit provided	25,200,000	'	25,200,000
Environmental Restoration Costs [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Range of possible loss, minimum	119,500,000	'	119,500,000
Range of possible loss, maximum	223,500,000	'	223,500,000
Environmental Restoration Costs [Member] | Sites Comprising the Majority the Environmental Remediation [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Range of possible loss, minimum	100,400,000	'	100,400,000
Range of possible loss, maximum	$192,800,000	'	$192,800,000
Number of sites affected by environmental remediation	6	'	6

FAIR_VALUE_OF_FINANCIAL_ASSETS2

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) (Fair Value, Measurements, Recurring [Member], USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Total [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	$8,696	[1]	$7,520	[1]
Derivatives - Energy Related Assets	1,500	[2]	766	[2]
Total Assets	10,196		8,286
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	759	[2]	2,695	[2]
Derivatives - Other	3,735	[3]	7,761	[3]
Total Liabilities	4,494		10,456
Level 1 [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	8,696	[1]	769	[1]
Derivatives - Energy Related Assets	1,409	[2]	447	[2]
Total Assets	10,105		1,216
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	155	[2]	2,694	[2]
Derivatives - Other	0	[3]	0	[3]
Total Liabilities	155		2,694
Level 2 [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	0	[1]	6,751	[1]
Derivatives - Energy Related Assets	91	[2]	319	[2]
Total Assets	91		7,070
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	604	[2]	1	[2]
Derivatives - Other	3,735	[3]	7,761	[3]
Total Liabilities	4,339		7,762
Level 3 [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	0	[1]	0	[1]
Derivatives - Energy Related Assets	0	[2]	0	[2]
Total Assets	0		0
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	0	[2]	0	[2]
Derivatives - Other	0	[3]	0	[3]
Total Liabilities	$0		$0
[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. 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, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

DERIVATIVE_INSTRUMENTS_Details

DERIVATIVE INSTRUMENTS (Details) (USD $)	1 Months Ended
	Sep. 30, 2005	Dec. 31, 2013	Dec. 31, 2012
Derivative [Line Items]	'	'	'
Unrealized gain (losses) included in its BGSS related to open financial contracts	'	$700,000	($1,900,000)
Initial cost of Treasury Locks	1,400,000	'	'
Amortization period of Treasury Locks	'30 years	'	'
Unamortized balance of Treasury Locks	'	1,000,000	1,100,000
South Jersey Gas Company [Member] | Interest Rate Swap, $12,500,000 Contract 1 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Derivative, Notional Amount	'	12,500,000,000	'
Derivative, Fixed Interest Rate	'	3.43%	'
South Jersey Gas Company [Member] | Interest Rate Swap, $12,500,000 Contract 2 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Derivative, Notional Amount	'	$12,500,000,000	'
Derivative, Fixed Interest Rate	'	3.43%	'
Natural Gas (in MMdts) [Member] | Derivative Transaction Type, Purchase [Member]	'	'	'
Derivative [Line Items]	'	'	'
Outstanding derivative contracts notional amount	'	6.6	'

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	$1,500	$766
Fair value Derivative Liabilities	4,494	10,456
Commodity Contract [Member] | Derivatives-Energy Related-Current [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	1,222	464
Fair value Derivative Liabilities	711	2,615
Commodity Contract [Member] | Derivatives-Energy Related-NonCurrent [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	278	302
Fair value Derivative Liabilities	48	80
Interest Rate Contract [Member] | Derivatives-Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$3,735	$7,761

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	$1,500	$766
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	1,500	766
Gross amounts not offset in the balance sheet, Financial Instruments	-155	-447	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	-498	0
Net amount	847	319
Offsetting Derivative Liabilities [Abstract]	'	'
Gross amounts of recognized assets/liabilities	-759	-2,695
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	-759	-2,695
Gross amounts not offset in the balance sheet, Financial Instruments	155	447	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0	1,136
Net amount	-604	-1,112
Derivatives - Other [Member]	'	'
Offsetting Derivative Liabilities [Abstract]	'	'
Gross amounts of recognized assets/liabilities	-3,735	-7,761
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	-3,735	-7,761
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	($3,735)	($7,761)
[1]	The balances at December 31, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at December 31, 2013 and December 31, 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
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'		'		'
Losses reclassified from accumulated OCI into income	($46,000)	[1]	($46,000)	[1]	($46,000)	[1]
Realized gains losses, derivative instruments on energy-related contracts	$400,000		$15,400,000		$12,900,000
[1]	Included in Interest Charges

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]	'		'		'
Beginning balance	($13,285)	[1]	'		'
Other comprehensive income before reclassifications	1,524		'		'
Amounts reclassified from AOCL	892	[2]	'		'
Other Comprehensive Gain (Loss) - Net of Tax	2,416	[1]	-1,156	[1]	-3,009	[1]
Ending balance	-10,869	[1]	-13,285	[1]	'
Combined statutory tax rate	41.00%		'		'
Postretirement Liability Adjustment [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Beginning balance	-12,958	[1]	-11,275	[1]	-8,599	[1]
Other comprehensive income before reclassifications	932		'		'
Amounts reclassified from AOCL	1,354	[2]	'		'
Other Comprehensive Gain (Loss) - Net of Tax	2,286	[1]	-1,683	[1]	-2,676	[1]
Ending balance	-10,672	[1]	-12,958	[1]	-11,275	[1]
Unrealized Gain (Loss) on Derivatives-Other [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Beginning balance	-621	[1]	-648	[1]	-675	[1]
Other comprehensive income before reclassifications	0		'		'
Amounts reclassified from AOCL	27	[2]	'		'
Other Comprehensive Gain (Loss) - Net of Tax	27	[1]	27	[1]	27	[1]
Ending balance	-594	[1]	-621	[1]	-648	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Beginning balance	294	[1]	-206	[1]	154	[1]
Other comprehensive income before reclassifications	592		'		'
Amounts reclassified from AOCL	-489	[2]	'		'
Other Comprehensive Gain (Loss) - Net of Tax	103	[1]	500	[1]	-360	[1]
Ending balance	$397	[1]	$294	[1]	($206)	[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]

'

'

'

'

'

'

'

'

'

'

'

Interest Charges

'

'

'

'

'

'

'

'

($12,550)

($12,427)

($18,922)

Other Income & Expense

'

'

'

'

'

'

'

'

-3,797

-2,617

-3,429

Operations

'

'

'

'

'

'

'

'

85,805

78,425

68,149

Income Before Income Taxes

'

'

'

'

'

'

'

'

-97,069

-91,952

-87,170

Income Taxes

-11,322

-471

-2,269

-20,771

-10,589

-258

-1,887

-20,977

-34,833

-33,711

-34,281

Net Income

-21,953

-949

-3,821

-35,513

-19,443

-523

-3,237

-35,038

-62,236

-58,241

-52,889

Amounts Reclassified from AOCL [Member]

'

'

'

'

'

'

'

'

'

'

'

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Income Before Income Taxes

'

'

'

'

'

'

'

'

1,507

'

'

Income Taxes

'

'

'

'

'

'

'

'

615

[1]

'

'

Net Income

'

'

'

'

'

'

'

'

892

'

'

Amounts Reclassified from AOCL [Member] | Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges [Member]

'

'

'

'

'

'

'

'

'

'

'

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Interest Charges

'

'

'

'

'

'

'

'

-46

'

'

Amounts Reclassified from AOCL [Member] | Unrealized Gain (Loss) on Available-for-Sale Securities [Member]

'

'

'

'

'

'

'

'

'

'

'

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Other Income & Expense

'

'

'

'

'

'

'

'

-828

'

'

Amounts Reclassified from AOCL [Member] | Postretirement Liability Adjustment [Member]

'

'

'

'

'

'

'

'

'

'

'

Reclassification out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operations

'

'

'

'

'

'

'

'

$2,289

'

'

[1]

Determined using a combined statutory tax rate of 41%.

QUARTERLY_RESULTS_OF_OPERATION2

QUARTERLY RESULTS OF OPERATIONS - UNAUDITED (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
Quarterly Financial Information Disclosure [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenues	$146,172	$59,674	$66,536	$174,098	$129,010	$54,251	$59,177	$179,436	$446,480	$421,874	$412,449
Expenses:	'	'	'	'	'	'	'	'	'	'	'
Cost of Sales (excluding depreciation)	71,654	24,717	26,108	77,602	60,751	21,053	20,407	86,499	200,081	188,710	187,866
Operations and Maintenance Including Fixed Charges	39,486	33,249	33,871	38,659	33,877	32,953	33,597	35,102	'	'	'
Income Taxes	11,322	471	2,269	20,771	10,589	258	1,887	20,977	34,833	33,711	34,281
Energy and Other Taxes	2,530	1,052	1,277	3,003	2,485	1,167	1,479	3,169	7,862	8,300	10,291
Total Expenses	124,992	59,489	63,525	140,035	107,702	55,431	57,370	145,747	'	'	'
Other Income and Expense	773	764	810	1,450	-1,865	1,703	1,430	1,349	'	'	'
Net Income	$21,953	$949	$3,821	$35,513	$19,443	$523	$3,237	$35,038	$62,236	$58,241	$52,889

SUBSEQUENT_EVENT_Details

SUBSEQUENT EVENT (Details) (USD $)	1 Months Ended
	Oct. 31, 2013	Oct. 31, 2013	Jan. 31, 2014
		Maximum [Member]	Subsequent Event [Member]
			Mortgages [Member]
Subsequent Event [Line Items]	'	'	'
Debt Instrument, Face Amount	'	'	$30,000,000
Debt Instrument, Interest Rate, Stated Percentage	'	'	4.23%
Amount of Additional Debt Petitioned For	'	$200,000,000	'
Amount of Additional Debt Petitioned For, Period	'3 years	'	'

SCHEDULE_II_VALUATION_AND_QUAL1

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Movement in Valuation Allowances and Reserves [Roll Forward]	'		'		'
Balance	$3,985		$3,060		$4,577
Charged to Costs and Expenses	4,232		4,775		1,410
Charged to Other Accounts	-41	[1]	110	[1]	562	[1]
Deductions	3,623	[2]	3,960	[2]	3,489	[2]
Balance	$4,553		$3,985		$3,060
[1]	Recoveries of accounts previously written off and minor adjustments.
[2]	Uncollectible accounts written off.