SOUTH JERSEY GAS 10-Q 12 Nov 13 2013 Q3 Quarterly report Financial data

DOCUMENT_AND_ENTITY_INFORMATIO

DOCUMENT AND ENTITY INFORMATION Document	9 Months Ended
	Sep. 30, 2013	Nov. 01, 2013
Document and Entity Information [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-Q	'
Document Period End Date	30-Sep-13	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	2,339,139

CONDENSED_STATEMENTS_OF_INCOME

CONDENSED STATEMENTS OF INCOME (UNAUDITED) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Income Statement [Abstract]	'	'	'	'
Operating Revenues	$59,674	$54,251	$300,308	$292,864
Operating Expenses:	'	'	'	'
Cost of Sales (Excluding depreciation)	24,717	21,053	128,427	127,959
Operations	18,613	17,536	62,132	56,677
Maintenance	3,353	3,570	10,140	10,133
Depreciation	8,654	7,975	25,128	23,010
Energy and Other Taxes	1,052	1,167	5,332	5,815
Total Operating Expenses	56,389	51,301	231,159	223,594
Operating Income	3,285	2,950	69,149	69,270
Other Income and Expense	764	1,703	3,024	4,482
Interest Charges	-2,629	-3,872	-8,379	-11,832
Income Before Income Taxes	1,420	781	63,794	61,920
Income Taxes	-471	-258	-23,511	-23,122
Net Income	$949	$523	$40,283	$38,798

CONDENSED_STATEMENTS_OF_COMPRE

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Statement of Other Comprehensive Income [Abstract]	'		'		'		'
Net Income	$949		$523		$40,283		$38,798
Other Comprehensive (Loss) Gain - Net of Tax:	'		'		'		'
Unrealized (Loss) Gain on Available-for-Sale Securities	221	[1]	205	[1]	-76	[1]	420	[1]
Unrealized Gain on Derivatives - Other	7	[1]	7	[1]	21	[1]	21	[1]
Other Comprehensive (Loss) Gain - Net of Tax	228	[1]	212	[1]	-55	[1]	441	[1]
Comprehensive Income	$1,177		$735		$40,228		$39,239
Combined statutory tax rate	41.00%		41.00%		41.00%		41.00%
[1]	Determined using a combined statutory tax rate of 41% .

CONDENSED_STATEMENTS_OF_CASH_F

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Statement of Cash Flows [Abstract]	'	'
Net Cash Provided by Operating Activities	$109,974	$51,006
Cash Flows from Investing Activities:	'	'
Capital Expenditures	-118,383	-114,886
Net (Purchase) Sale of Restricted Investments in Margin Accounts	-809	641
Investment in Long-Term Receivables	-5,012	-4,178
Proceeds from Long-Term Receivables	5,376	5,217
Net Cash Used in Investing Activities	-118,828	-113,206
Cash Flows from Financing Activities:	'	'
Net Borrowing from Short-Term Credit Facilities	7,900	11,300
Proceeds from Issuance of Long-Term Debt	0	85,000
Principal Repayments of Long-Term Debt	-25,000	-35,000
Premium for Early Retirement of Debt	0	-700
Payments for Issuance of Long-Term Debt	-30	-936
Additional Investment by Shareholder	25,000	0
Net Cash Provided by Financing Activities	7,870	59,664
Net Decrease in Cash and Cash Equivalents	-984	-2,536
Cash and Cash Equivalents at Beginning of Period	2,678	3,504
Cash and Cash Equivalents at End of Period	$1,694	$968

CONDENSED_BALANCE_SHEETS_UNAUD

CONDENSED BALANCE SHEETS (UNAUDITED) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Property, Plant and Equipment:	'		'
Utility Plant, at original cost	$1,776,502		$1,658,790
Accumulated Depreciation	-388,511		-373,199
Property, Plant and Equipment - Net	1,387,991		1,285,591
Investments:	'		'
Available-for-Sale Securities	8,237		7,520
Restricted Investments	2,077		1,268
Total Investments	10,314		8,788
Current Assets:	'		'
Cash and Cash Equivalents	1,694		2,678
Accounts Receivable	50,137		49,071
Accounts Receivable - Related Parties	1,316		961
Unbilled Revenues	7,464		35,351
Provision for Uncollectibles	-5,618		-3,985
Natural Gas in Storage, average cost	27,753		13,896
Materials and Supplies, average cost	1,682		1,560
Deferred Income Taxes - Net	9,759		0
Prepaid Taxes	14,108		17,046
Derivatives - Energy Related Assets	239		464
Other Prepayments and Current Assets	4,644		3,343
Total Current Assets	113,178		120,385
Regulatory and Other Noncurrent Assets:	'		'
Regulatory Assets	326,727		352,656
Unamortized Debt Issuance Costs	6,282		6,663
Long-Term Receivables	9,458		9,336
Derivatives - Energy Related Assets	67		302
Other	3,170		2,738
Total Regulatory and Other Noncurrent Assets	345,704		371,695
Total Assets	1,857,187		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	226,050		201,050
Accumulated Other Comprehensive Loss	-13,340	[1]	-13,285	[1]
Retained Earnings	368,065		327,782
Total Common Equity	586,623		521,395
Long-Term Debt	404,000		425,000
Total Capitalization	990,623		946,395
Current Liabilities:	'		'
Notes Payable	110,000		102,100
Current Portion of Long-Term Debt	21,000		25,000
Accounts Payable - Commodity	11,682		14,926
Accounts Payable - Other	31,279		25,498
Accounts Payable - Related Parties	5,506		5,872
Derivatives - Energy Related Liabilities	1,606		2,615
Deferred Income Taxes - Net	0		10,432
Customer Deposits and Credit Balances	20,482		17,450
Environmental Remediation Costs	25,662		19,203
Taxes Accrued	1,470		1,674
Pension Benefits	1,236		1,236
Interest Accrued	4,248		6,277
Other Current Liabilities	3,331		6,492
Total Current Liabilities	237,502		238,775
Regulatory and Other Noncurrent Liabilities:	'		'
Regulatory Liabilities	52,219		56,517
Deferred Income Taxes - Net	352,845		310,357
Environmental Remediation Costs	82,574		88,207
Asset Retirement Obligations	39,645		38,892
Pension and Other Postretirement Benefits	86,431		89,193
Investment Tax Credits	424		618
Derivatives - Energy Related Liabilities	179		80
Derivatives - Other	4,569		7,761
Other	10,176		9,664
Total Regulatory and Other Noncurrent Liabilities	629,062		601,289
Commitments and Contingencies (Note 9)	'		'
Total Capitalization and Liabilities	$1,857,187		$1,786,459
[1]	Determined using a combined statutory tax rate of 41% .

CONDENSED_BALANCE_SHEETS_UNAUD1

CONDENSED BALANCE SHEETS (UNAUDITED) (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]	'	'
Common Stock, Par Value (in dollars per share)	$2.50	$2.50
Authorized (in shares)	4,000,000	4,000,000
Outstanding (in shares)	2,339,139	2,339,139

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
	Sep. 30, 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), a regulated natural gas utility. SJG distributes natural gas in the seven southern most counties of New Jersey. In our opinion, the condensed 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. SJG’s business is subject to seasonal fluctuations and accordingly, this interim financial information should not be the basis for estimating the full year’s operating results. As permitted by the rules and regulations of the Securities and Exchange Commission, the accompanying condensed financial statements contain certain condensed financial information and exclude certain note disclosures normally included in annual audited financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These condensed financial statements should be read in conjunction with SJG’s 2012 Form 10-K for a more complete discussion of our accounting policies and certain other information.
	REVENUE AND THROUGHPUT - BASED TAXES - SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both revenues and cost of sales, and totaled $0.5 million and $0.7 million for the three months ended September 30, 2013 and 2012, and $3.4 million and $4.0 million for the nine months ended September 30, 2013 and 2012, respectively. The TEFA is subject to a planned phase-out which decreased the assessment in increments of 25% in 2012 and 2013 and is eliminated after December 31, 2013.
	NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2012 and 2013 had, or is expected to have, a material impact on the condensed 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 is effective for fiscal years beginning on or after January 1, 2013. The adoption of this guidance modified the disclosures around derivative instruments, but did not have an impact on the Company's financial statement results.
	In February 2013, in response to ASU 2011-12 discussed above, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.
	In July 2013, the FASB issued ASU 2013-11, Balance Sheet Presentation of an Unrecognized Income Tax Benefit for a Net Operating Loss or Tax Credit Carryforward. This ASU provides that a liability related to an unrecognized tax benefit should be offset against a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. Management does not anticipate that the adoption of this guidance will have an impact on the Company's financial statement results.

STOCKBASED_COMPENSATION_PLANS

STOCK-BASED COMPENSATION PLANS	9 Months Ended
	Sep. 30, 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. 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.
	See Note 2 to the Financial Statements in Item 8 of SJG Annual Report on Form 10-K as of December 31, 2012 for the related accounting policy.
	The following table summarizes the SJI nonvested restricted stock awards pertaining to SJG outstanding at September 30, 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. 2011 - TSR		7,116		$	50.94	27.5	%	1.01	%
	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 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 during 2013 and 2012 is approximately $0.1 million per quarter.
	As of September 30, 2013, there was $0.5 million of total unrecognized compensation cost related to nonvested share-based compensation awards granted under the restricted stock plans. That cost is expected to be recognized over a weighted average period of 1.8 years.
	The following table summarizes information regarding restricted stock award activity during the nine months ended September 30, 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
	Canceled / Forfeited	(2,248	)	$	50.02
	Nonvested Shares Outstanding, September 30, 2013	22,184		$	50.8
	During the nine months ended September 30, 2013, SJI awarded 12,901 shares that had vested at December 31, 2012, to SJG's officers and other key employees at a market value of $0.6 million. During the nine months ended September 30, 2012, SJI awarded 7,098 shares at a market value of $0.4 million to SJG's officers and other key employees. SJG has a policy of making cash payments to SJI to satisfy its obligations under this plan. Cash payments to SJI during each of the nine months ended September 30, 2013 and 2012 were approximately $0.4 million 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	9 Months Ended
	Sep. 30, 2013
Public Utilities, General Disclosures [Abstract]	'
RATES AND REGULATORY ACTIONS	'
	RATES AND REGULATORY ACTIONS:
	SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). In January 2013, SJG credited the accounts of our periodic Basic Gas Supply Service (BGSS) customers with refunds totaling $9.4 million due to gas costs that were lower than projected.
	In January 2013, the BPU approved an extension of the Company's Energy Efficiency Program (“EEP”) to June 30, 2013 and approved additional investments of up to $2.5 million. In June 2013, the BPU approved a further extension of SJG's EEP through June 2015 and authorized incremental investments totaling $24.0 million . The costs and returns associated with the EEP program investments will continue to be recovered through the Company's Energy Efficiency Tracker (“EET”).
	In June 2013, SJG filed its annual EET petition requesting additional revenues to recover the costs of, and its allowed return on, prior investments associated with the EEP programs. This petition is currently pending.
	In July 2012, SJG filed a petition with the BPU to implement a five-year, $250.0 million Accelerated Infrastructure Replacement Program (“AIRP”). The Company proposed spending an incremental $50.0 million per year on the accelerated replacement of its cast iron and bare steel main and service infrastructure and was seeking a return on program investments as it had under prior Capital Investment Recovery Tracker ("CIRT") programs. SJG's CIRT III program expired on December 31, 2012. In February 2013, the parties executed a Stipulation agreeing to $35.3 million per year of incremental capital spending for four years, totaling $141.2 million under the AIRP. The BPU approved the Stipulation in February 2013.
	In March 2013, SJG filed a joint petition with another utility requesting modifications to, and the continuation of, the Conservation Incentive Plan (“CIP”) program. This petition is currently pending.
	In May 2013, SJG made its annual BGSS and CIP filing requesting a $17.9 million decrease in annual revenues. Provisional rates were approved by the BPU in September 2013 and effective October 1, 2013.
	In June 2013, SJG filed a petition requesting deferral of incremental operating and maintenance expenses incurred due to Superstorm Sandy. These costs totaled $0.7 million and are expected to be recovered in SJG's next base rate case. This petition is currently pending.
	In October 2012, SJG filed a petition requesting a $13.2 million increase in annual revenues by rolling $110.6 million of CIRT I, II and III investments into base rates. In May 2013, SJG filed a supplemental petition requesting to roll an additional $6.9 million of CIRT III investments into base rates, for a total annual revenue increase of $15.5 million related to $117.5 million of CIRT investments made since our last base rate case in 2010. The BPU approved the petition in September 2013 with rates effective October 1, 2013.
	In September 2013, SJG filed a petition requesting a Storm Hardening and Reliability Program (SHARP), pursuant to which SJG is proposing to invest approximately $280 million over seven years to replace low pressure distribution mains and services with high pressure distribution mains and services in coastal areas that are susceptible to flooding during major storm events. This petition is currently pending.
	There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2012. See Note 3 to the Financial Statements in Item 8 of SJG's Form 10-K as of December 31, 2012.

REGULATORY_ASSETS_AND_LIABILIT

REGULATORY ASSETS AND LIABILITIES	9 Months Ended
	Sep. 30, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
REGULATORY ASSETS AND LIABILITIES	'
	REGULATORY ASSETS AND LIABILITIES:
	There have been no significant changes to the nature of SJG’s regulatory assets and liabilities since December 31, 2012, which are described in Notes 3 and 4 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012.
	Regulatory Assets consisted of the following items (in thousands):
		September 30, 2013		December 31, 2012
	Environmental Remediation Costs:
	Expended - Net	$	30,189	$	37,892
	Liability for Future Expenditures	108,236		107,410
	Deferred Asset Retirement Obligation Costs	30,607		30,199
	Deferred Pension and Other Postretirement Benefit Costs	95,897		95,897
	Conservation Incentive Program Receivable	12,573		31,686
	Societal Benefit Costs Receivable	12,816		12,801
	Premium for Early Retirement of Debt	976		1,075
	Deferred Interest Rate Contracts (Note 11)	4,569		7,761
	Energy Efficiency Tracker	12,263		12,306
	Pipeline Supplier Service Charges	7,522		8,771
	Other Regulatory Assets	11,079		6,858
	Total Regulatory Assets	$	326,727	$	352,656
	CONSERVATION INCENTIVE PROGRAM (CIP) RECEIVABLE – The decrease in this receivable is primarily the result of colder weather experienced in the region during the first half of 2013. The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer.
	Regulatory Liabilities consisted of the following items (in thousands):
		September 30, 2013		December 31, 2012
	Excess Plant Removal Costs	$	41,128	$	45,593
	Deferred Revenues-Net	8,352		10,924
	Other Regulatory Liabilities	2,739		—
	Total Regulatory Liabilities	$	52,219	$	56,517
	DEFERED REVENUES - NET - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	RELATED PARTY TRANSACTIONS:
	There have been no significant changes in the nature of SJG’s related party transactions since December 31, 2012. See Note 5 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012 for a detailed description of such transactions.
	A summary of related party transactions, excluding pass-through items, included in Operating Revenues were as follows, (in thousands):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Operating Revenues/Affiliates:
	SJRG	$	344		$	211		$	1,194		$	483
	Other	335			312			974			499
	Total Operating Revenue/Affiliates	$	679		$	523		$	2,168		$	982
	Related party transactions, excluding pass-through items, included in Operating Expenses were as follows, (in thousands):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Costs of Sales/Affiliates (Excluding depreciation):
	SJRG	$	5,436		$	2,683		$	11,105		$	8,445
	Energy-Related Derivative (Gains) / Losses *
	SJRG	$	389		$	3,011		$	568		$	13,666
	* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.
	Operations Expense/Affiliates
	SJI	$	2,737		$	2,237		$	8,613		$	7,400
	SJIS	1,330			1,240			4,264			3,833
	Millennium	665			796			2,014			2,379
	Other	(103		)	(99		)	(336		)	(377		)
	Total Operations Expense/Affiliates	$	4,629		$	4,174		$	14,555		$	13,235

FINANCIAL_INSTRUMENTS

FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2013
Financial Instruments, Owned, at Fair Value [Abstract]	'
FINANCIAL INSTRUMENTS	'
	FINANCIAL INSTRUMENTS:
	RESTRICTED INVESTMENTS - In accordance with the terms of our tax-exempt first mortgage bonds, unused proceeds are required to be escrowed pending approved construction expenditures. As of both September 30, 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 11. 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 September 30, 2013 and December 31, 2012, the balance held with SJRG totaled $0.9 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 11. The funds provided by SJG will increase or decrease as the number and value of outstanding energy-related contracts held with this counterparty changes. As of September 30, 2013 the balance held with this counterparty totaled $1.0 million. The carrying amounts of the Restricted Investments approximate their fair value at September 30, 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 $14.0 million and $13.6 million as of September 30, 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 condensed 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 September 30, 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 September 30, 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 approximate their fair values at September 30, 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 10 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJG's long-term debt, including current maturities, as of September 30, 2013 and December 31, 2012, were $446.2 million and $502.0 million, respectively.  The carrying amount of SJG's long-term debt, including current maturities, as of September 30, 2013 and December 31, 2012 was $425.0 million and $450.0 million respectively.

UNUSED_LINES_OF_CREDIT

UNUSED LINES OF CREDIT	9 Months Ended
	Sep. 30, 2013
Line of Credit Facility [Abstract]	'
UNUSED LINES OF CREDIT	'
	UNUSED LINES OF CREDIT:
	Credit facilities and available liquidity as of September 30, 2013 were as follows (in thousands):
		Total Facility		Usage		Available Liquidity		Expiration Date
	Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	110,000	$	90,000	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total	$	210,000	$	110,000	$	100,000
	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 September 30, 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 during the nine months ended September 30, 2013 and 2012 were $90.5 million and $146.3 million, respectively.  The maximum amount outstanding under these credit facilities during the nine months ended September 30, 2013 and 2012 were $119.9 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 0.34% and 0.47% at September 30, 2013 and 2012, respectively.

PENSION_AND_OTHER_POSTRETIREME

PENSION AND OTHER POSTRETIREMENT BENEFITS	9 Months Ended
	Sep. 30, 2013
Compensation and Retirement Disclosure [Abstract]	'
PENSION AND OTHER POSTRETIREMENT BENEFITS	'
	PENSION AND OTHER POSTRETIREMENT BENEFITS:
	For the three and nine months ended  September 30, 2013 and 2012, 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						Pension Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Service Cost	$	1,040		$	873		$	3,120		$	2,619
	Interest Cost	1,811			1,853			5,434			5,559
	Expected Return on Plan Assets	(2,286		)	(1,991		)	(6,859		)	(5,974		)
	Amortizations:
	Prior Service Cost	48			48			144			145
	Actuarial Loss	1,729			1,469			5,185			4,407
	Net Periodic Benefit Cost	2,342			2,252			7,024			6,756
	Capitalized Benefit Costs	(1,218		)	(1,306		)	(3,653		)	(3,513		)
	Total Net Periodic Benefit Expense	$	1,124		$	946		$	3,371		$	3,243
		Other Postretirement Benefits						Other Postretirement Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Service Cost	$	212		$	198		$	637		$	594
	Interest Cost	509			573			1,526			1,719
	Expected Return on Plan Assets	(443		)	(402		)	(1,329		)	(1,206		)
	Amortizations:
	Prior Service Credits	(53		)	(54		)	(159		)	(162		)
	Actuarial Loss	324			329			972			988
	Net Periodic Benefit Cost	549			644			1,647			1,933
	Capitalized Benefit Costs	(285		)	(374		)	(856		)	(1,005		)
	Total Net Periodic Benefit Expense	$	264		$	270		$	791		$	928
	Capitalized benefit costs reflected in the table above relate to our construction program.
	SJG contributed $9.1 million and $19.8 million to the pension plans in January 2013 and 2012, respectively. No additional contributions are expected to be made to the pension plans during 2013. Payments related to the unfunded Supplemental Executive Retirement Plan (SERP) are expected to approximate $1.2 million in 2013. We also have a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred.
	See Note 11 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012 for additional information related to SJG’s pension and other postretirement benefits.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 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.
	ENVIRONMENTAL REMEDIATION COSTS - SJG incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. There have been no significant changes to the status of SJG’s environmental remediation efforts since December 31, 2012, as described in Note 12 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012.
	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 $4.3 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 $0.4 million and $0.5 million related to all claims in the aggregate, as of September 30, 2013 and December 31, 2012, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.
	COLLECTIVE BARGAINING AGREEMENTS - Unionized personnel represent approximately 60% of our workforce at September 30, 2013. The Company has collective bargaining agreements with two unions who represent these employees: the International Brotherhood of Electrical Workers (IBEW) operates under a collective bargaining agreement that runs through February 28, 2017, and the International Association of Machinists and Aerospace Workers (IAM) operates under a collective bargaining agreement that expires in August 2014.

FAIR_VALUE_OF_FINANCIAL_ASSETS

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	9 Months Ended
	Sep. 30, 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 September 30, 2013
		Total				Level 1			Level 2		Level 3
	Assets -
	Available-for-Sale Securities (A)	$	8,237			$	8,237		$	—	$	—
	Derivatives – Energy Related Assets (B)	306				306			—		—
		$	8,543			$	8,543		$	—	$	—
	Liabilities -
	Derivatives – Energy Related Liabilities (B)	$	1,785			$	1,466		$	—	$	319
	Derivatives – Other (C)	4,569				—			4,569		—
		$	6,354			$	1,466		$	4,569	$	319
	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 consisted of funds that are not publicly traded.  These funds, which consisted 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. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.
	Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
	(C)  Derivatives – Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model.  Market inputs can generally be verified and model selection does not involve significant management judgment.
	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands):
	Type	Fair Value at September 30, 2013		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets	Liabilities
	Forward Contract - Natural Gas	$—	$319	Discounted Cash Flow	Forward price (per dt)	$(1.75) - $(1.75) [$(1.75)]
	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and nine months ended September 30, 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
		Three Months				Nine Months Ended
		Ended				30-Sep-13
		30-Sep-13
	Balance at beginning of period	$	(243	)		$	—
	Total losses unrealized in Regulatory Liabilities (see note 4)	(76		)		(319		)
	Settlements	—				—
		(76		)		(319		)
	Balance at September 30	$	(319	)		$	(319	)

DERIVATIVE_INSTRUMENTS

DERIVATIVE INSTRUMENTS	9 Months Ended
	Sep. 30, 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 September 30, 2013, SJG had outstanding derivative contracts intended to limit the exposure to market risk on 6.5 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 condensed 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 condensed balance sheets. As of September 30, 2013 and December 31, 2012, SJG had $1.5 million 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 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 condensed balance sheets. The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates. There have been no significant changes to the Company’s active interest rate swaps since December 31, 2012 which are described in Note 1 to the Financial Statements in Item 8 of SJG’s Annual Report on Form 10-K as of December 31, 2012. 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 condensed balance sheets.
	We previously used derivative transactions known as “Treasury Locks” to hedge 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 September 30, 2013 and December 31, 2012, the unamortized balance was approximately $1.0 million and $1.1 million, respectively.
	The fair values of all derivative instruments, as reflected in the condensed balance sheets as of September 30, 2013 and December 31, 2012, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	September 30, 2013						December 31, 2012
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	239		$	1,606		$	464		$	2,615
	Derivatives – Energy Related – Non-Current	67			179			302			80
	Interest rate contracts:
	Derivatives – Other	—			4,569			—			7,761
	Total derivatives not designated as hedging instruments under GAAP	306			6,354			766			10,456
	Total Derivatives	$	306		$	6,354		$	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 September 30, 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	$	306		$	—		$	306		$	(306	)	(A)	$	—	$	—
	Derivatives - Energy Related Liabilities	(1,785		)	—			(1,785		)	306			(B)	1,160		(319		)
	Derivatives - Other	(4,569		)	—			(4,569		)	—				—		(4,569		)
	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 September 30, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at September 30, 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 condensed statements of income for the three and nine months ended September 30, 2013 and 2012 are as follows (in thousands):
		Three months ended						Nine months ended
		September 30,						September 30,
	Derivatives in Cash Flow Hedging Relationships	2013			2012			2013			2012
	Interest Rate Contracts:
	Losses reclassified from accumulated OCL into income (a)	$	(12	)	$	(12	)	$	(36	)	$	(36	)
	(a) Included in Interest Charges
	Net realized losses of $0.4 million and $3.0 million associated with SJG's energy related financial commodity contracts for the three months ended September 30, 2013 and 2012 and losses of $0.6 million and $13.7 million for the nine months ended September 30, 2013 and 2012, 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.

LONGTERM_DEBT

LONG-TERM DEBT	9 Months Ended
	Sep. 30, 2013
Long-term Debt, Unclassified [Abstract]	'
LONG-TERM DEBT	'
	LONG-TERM DEBT:
	In February 2012, SJG called its $35.0 million, 7.70% Medium Term Notes (MTN's) due April 2027 at par, plus a 2.0% premium. The early redemption occurred concurrently with the issuance in April 2012 of $35.0 million, 3.74% Series D MTN due April 2032.
	During the third quarter of 2013, SJG redeemed at par $10.5 million of 4.46% MTN's issued in July 2003 and $14.5 million of 5.027% MTN's issued in September 2003.
	In September 2013, SJG agreed in principle to issue $80.0 million of MTN's under a private placement. SJG expects to issue $50.0 million of 4.01% MTN's in November 2013, due November 2030, and $30.0 million of 4.23% MTN's in January 2014, due January 2030.
	We retire debt when it is cost effective as permitted by the debt agreements.  Our long-term debt agreements contain no financial covenants.
	The Company did not issue any long-term debt during the nine months ended September 30, 2013.

ACCUMULATED_OTHER_COMPREHENSIV

ACCUMULATED OTHER COMPREHENSIVE LOSS	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
ACCUMULATED OTHER COMPREHENSIVE LOSS	'
	ACCUMULATED OTHER COMPREHENSIVE LOSS:
	The changes in Accumulated Other Comprehensive Loss (AOCL) for the three and nine months ended September 30, 2013 are as follows (in thousands):
		Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Total
	Balance at July 1, 2013 (a)	$	(12,958	)	$	(607	)	$	(3	)	$	(13,568	)
	Other comprehensive income before reclassifications	—			—			221			221
	Amounts reclassified from AOCL (b)	—			7			—			7
	Net current period other comprehensive income (loss)	—			7			221			228
	Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)
		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	—			—			413			413
	Amounts reclassified from AOCL (b)	—			21			(489		)	(468		)
	Net current period other comprehensive income (loss)	—			21			(76		)	(55		)
	Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
	The reclassifications out of AOCL and into earnings during the three and nine months ended September 30, 2013 is as follows (in thousands):
	Components of AOCL	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Statements of Income
		Three Months Ended			Nine Months Ended
		30-Sep-13			30-Sep-13
	Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		$	36		Interest Charges
	Unrealized Gain on Available-for-Sale Securities	—			(828		)	Other Income & Expense
		12			(792		)	Loss (Income) Before Income Taxes
	Income Taxes (a)	(5		)	324			Income Taxes (a)
	Losses (Gains) from reclassifications for the period net of tax	$	7		$	(468	)
	(a) Determined using a combined statutory tax rate of 41%.

EQUITY_CONTRIBUTIONS

EQUITY CONTRIBUTIONS	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
EQUITY CONTRIBUTIONS	'
	EQUITY CONTRIBUTION:
	We received an equity infusion of $25.0 million from SJI during September 2013. Contributions of capital are credited to Other Paid-In Capital and Premium on Common Stock. Further equity contributions will occur on an as needed basis.

SUBSEQUENT_EVENT

SUBSEQUENT EVENT	9 Months Ended
	Sep. 30, 2013
Subsequent Events [Abstract]	'
SUBSEQUENT EVENT	'
	SUBSEQUENT EVENT:
	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 is currently pending.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
REVENUE BASED TAXES	'
	REVENUE AND THROUGHPUT - BASED TAXES - SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both revenues and cost of sales, and totaled $0.5 million and $0.7 million for the three months ended September 30, 2013 and 2012, and $3.4 million and $4.0 million for the nine months ended September 30, 2013 and 2012, respectively. The TEFA is subject to a planned phase-out which decreased the assessment in increments of 25% in 2012 and 2013 and is eliminated after December 31, 2013.
NEW ACCOUNTING PRONOUNCEMENTS	'
	NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2012 and 2013 had, or is expected to have, a material impact on the condensed 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 is effective for fiscal years beginning on or after January 1, 2013. The adoption of this guidance modified the disclosures around derivative instruments, but did not have an impact on the Company's financial statement results.
	In February 2013, in response to ASU 2011-12 discussed above, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.
	In July 2013, the FASB issued ASU 2013-11, Balance Sheet Presentation of an Unrecognized Income Tax Benefit for a Net Operating Loss or Tax Credit Carryforward. This ASU provides that a liability related to an unrecognized tax benefit should be offset against a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. Management does not anticipate that the adoption of this guidance will have an impact on the Company's financial statement results.
FAIR VALUE	'
	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 consisted of funds that are not publicly traded.  These funds, which consisted 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. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.
	Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
	(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.

STOCKBASED_COMPENSATION_PLANS_

STOCK-BASED COMPENSATION PLANS (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 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. 2011 - TSR		7,116		$	50.94	27.5	%	1.01	%
	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 the nine months ended September 30, 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
	Canceled / Forfeited	(2,248	)	$	50.02
	Nonvested Shares Outstanding, September 30, 2013	22,184		$	50.8

REGULATORY_ASSETS_AND_LIABILIT1

REGULATORY ASSETS AND LIABILITIES (Tables)	9 Months Ended
	Sep. 30, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Schedule of Regulatory Assets	'
	Regulatory Assets consisted of the following items (in thousands):
		September 30, 2013		December 31, 2012
	Environmental Remediation Costs:
	Expended - Net	$	30,189	$	37,892
	Liability for Future Expenditures	108,236		107,410
	Deferred Asset Retirement Obligation Costs	30,607		30,199
	Deferred Pension and Other Postretirement Benefit Costs	95,897		95,897
	Conservation Incentive Program Receivable	12,573		31,686
	Societal Benefit Costs Receivable	12,816		12,801
	Premium for Early Retirement of Debt	976		1,075
	Deferred Interest Rate Contracts (Note 11)	4,569		7,761
	Energy Efficiency Tracker	12,263		12,306
	Pipeline Supplier Service Charges	7,522		8,771
	Other Regulatory Assets	11,079		6,858
	Total Regulatory Assets	$	326,727	$	352,656
Schedule of Regulatory Liabilities	'
	Regulatory Liabilities consisted of the following items (in thousands):
		September 30, 2013		December 31, 2012
	Excess Plant Removal Costs	$	41,128	$	45,593
	Deferred Revenues-Net	8,352		10,924
	Other Regulatory Liabilities	2,739		—
	Total Regulatory Liabilities	$	52,219	$	56,517

RELATED_PARTY_TRANSACTIONS_Tab

RELATED PARTY TRANSACTIONS (Tables)	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Summary of related party transactions	'
	A summary of related party transactions, excluding pass-through items, included in Operating Revenues were as follows, (in thousands):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Operating Revenues/Affiliates:
	SJRG	$	344		$	211		$	1,194		$	483
	Other	335			312			974			499
	Total Operating Revenue/Affiliates	$	679		$	523		$	2,168		$	982
	Related party transactions, excluding pass-through items, included in Operating Expenses were as follows, (in thousands):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Costs of Sales/Affiliates (Excluding depreciation):
	SJRG	$	5,436		$	2,683		$	11,105		$	8,445
	Energy-Related Derivative (Gains) / Losses *
	SJRG	$	389		$	3,011		$	568		$	13,666
	* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.
	Operations Expense/Affiliates
	SJI	$	2,737		$	2,237		$	8,613		$	7,400
	SJIS	1,330			1,240			4,264			3,833
	Millennium	665			796			2,014			2,379
	Other	(103		)	(99		)	(336		)	(377		)
	Total Operations Expense/Affiliates	$	4,629		$	4,174		$	14,555		$	13,235

UNUSED_LINES_OF_CREDIT_Tables

UNUSED LINES OF CREDIT (Tables)	9 Months Ended
	Sep. 30, 2013
Line of Credit Facility [Abstract]	'
Schedule of lines of credit	'
	Credit facilities and available liquidity as of September 30, 2013 were as follows (in thousands):
		Total Facility		Usage		Available Liquidity		Expiration Date
	Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	110,000	$	90,000	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total	$	210,000	$	110,000	$	100,000

PENSION_AND_OTHER_POSTRETIREME1

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	9 Months Ended
	Sep. 30, 2013
Compensation and Retirement Disclosure [Abstract]	'
Schedule of defined benefit plans disclosures	'
	For the three and nine months ended  September 30, 2013 and 2012, 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						Pension Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Service Cost	$	1,040		$	873		$	3,120		$	2,619
	Interest Cost	1,811			1,853			5,434			5,559
	Expected Return on Plan Assets	(2,286		)	(1,991		)	(6,859		)	(5,974		)
	Amortizations:
	Prior Service Cost	48			48			144			145
	Actuarial Loss	1,729			1,469			5,185			4,407
	Net Periodic Benefit Cost	2,342			2,252			7,024			6,756
	Capitalized Benefit Costs	(1,218		)	(1,306		)	(3,653		)	(3,513		)
	Total Net Periodic Benefit Expense	$	1,124		$	946		$	3,371		$	3,243
		Other Postretirement Benefits						Other Postretirement Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Service Cost	$	212		$	198		$	637		$	594
	Interest Cost	509			573			1,526			1,719
	Expected Return on Plan Assets	(443		)	(402		)	(1,329		)	(1,206		)
	Amortizations:
	Prior Service Credits	(53		)	(54		)	(159		)	(162		)
	Actuarial Loss	324			329			972			988
	Net Periodic Benefit Cost	549			644			1,647			1,933
	Capitalized Benefit Costs	(285		)	(374		)	(856		)	(1,005		)
	Total Net Periodic Benefit Expense	$	264		$	270		$	791		$	928

FAIR_VALUE_OF_FINANCIAL_ASSETS1

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 2013
		Total				Level 1			Level 2		Level 3
	Assets -
	Available-for-Sale Securities (A)	$	8,237			$	8,237		$	—	$	—
	Derivatives – Energy Related Assets (B)	306				306			—		—
		$	8,543			$	8,543		$	—	$	—
	Liabilities -
	Derivatives – Energy Related Liabilities (B)	$	1,785			$	1,466		$	—	$	319
	Derivatives – Other (C)	4,569				—			4,569		—
		$	6,354			$	1,466		$	4,569	$	319
	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 consisted of funds that are not publicly traded.  These funds, which consisted 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. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.
	Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
	(C)  Derivatives – Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model.  Market inputs can generally be verified and model selection does not involve significant management judgment.
Quantitative information regarding significant unobservable inputs in Level 3 fair value measurements	'
	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands):
	Type	Fair Value at September 30, 2013		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets	Liabilities
	Forward Contract - Natural Gas	$—	$319	Discounted Cash Flow	Forward price (per dt)	$(1.75) - $(1.75) [$(1.75)]
Changes in fair value of significant unobservable inputs	'
	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and nine months ended September 30, 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
		Three Months				Nine Months Ended
		Ended				30-Sep-13
		30-Sep-13
	Balance at beginning of period	$	(243	)		$	—
	Total losses unrealized in Regulatory Liabilities (see note 4)	(76		)		(319		)
	Settlements	—				—
		(76		)		(319		)
	Balance at September 30	$	(319	)		$	(319	)

DERIVATIVE_INSTRUMENTS_Tables

DERIVATIVE INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Fair value of derivative instruments	'
	The fair values of all derivative instruments, as reflected in the condensed balance sheets as of September 30, 2013 and December 31, 2012, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	September 30, 2013						December 31, 2012
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	239		$	1,606		$	464		$	2,615
	Derivatives – Energy Related – Non-Current	67			179			302			80
	Interest rate contracts:
	Derivatives – Other	—			4,569			—			7,761
	Total derivatives not designated as hedging instruments under GAAP	306			6,354			766			10,456
	Total Derivatives	$	306		$	6,354		$	766		$	10,456
Offsetting assets and liabilities	'
	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 September 30, 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	$	306		$	—		$	306		$	(306	)	(A)	$	—	$	—
	Derivatives - Energy Related Liabilities	(1,785		)	—			(1,785		)	306			(B)	1,160		(319		)
	Derivatives - Other	(4,569		)	—			(4,569		)	—				—		(4,569		)
	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 September 30, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at September 30, 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 condensed statements of income for the three and nine months ended September 30, 2013 and 2012 are as follows (in thousands):
		Three months ended						Nine months ended
		September 30,						September 30,
	Derivatives in Cash Flow Hedging Relationships	2013			2012			2013			2012
	Interest Rate Contracts:
	Losses reclassified from accumulated OCL into income (a)	$	(12	)	$	(12	)	$	(36	)	$	(36	)
	(a) Included in Interest Charges

ACCUMULATED_OTHER_COMPREHENSIV1

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Schedule of changes in accumulated other comprehensive loss (AOCL)	'
	The changes in Accumulated Other Comprehensive Loss (AOCL) for the three and nine months ended September 30, 2013 are as follows (in thousands):
		Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Total
	Balance at July 1, 2013 (a)	$	(12,958	)	$	(607	)	$	(3	)	$	(13,568	)
	Other comprehensive income before reclassifications	—			—			221			221
	Amounts reclassified from AOCL (b)	—			7			—			7
	Net current period other comprehensive income (loss)	—			7			221			228
	Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)
		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	—			—			413			413
	Amounts reclassified from AOCL (b)	—			21			(489		)	(468		)
	Net current period other comprehensive income (loss)	—			21			(76		)	(55		)
	Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
Reclassifications out of AOCL	'
	The reclassifications out of AOCL and into earnings during the three and nine months ended September 30, 2013 is as follows (in thousands):
	Components of AOCL	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Statements of Income
		Three Months Ended			Nine Months Ended
		30-Sep-13			30-Sep-13
	Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		$	36		Interest Charges
	Unrealized Gain on Available-for-Sale Securities	—			(828		)	Other Income & Expense
		12			(792		)	Loss (Income) Before Income Taxes
	Income Taxes (a)	(5		)	324			Income Taxes (a)
	Losses (Gains) from reclassifications for the period net of tax	$	7		$	(468	)
	(a) Determined using a combined statutory tax rate of 41%.

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Accounting Policies [Abstract]	'	'	'	'	'
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales	$0.50	$0.70	$3.40	$4	'
Decrease in TEFA revenue based tax rate	25.00%	'	25.00%	'	25.00%

STOCKBASED_COMPENSATION_PLANS_1

STOCK-BASED COMPENSATION PLANS (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'
Shares Outstanding (in shares)	22,184	'	22,184	'
Fair Value Per Share (in dollars per share)	$50.80	'	$50.80	'
Vesting period of shares	'	'	'3 years	'3 years
Cost of Restricted Stock Awards	$0.10	$0.10	'	'
Unrecognized compensation cost of awards granted under the plan	0.5	'	0.5	'
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	'	'	'1 year 9 months 18 days	'
Shares [Roll Forward]	'	'	'	'
Nonvested Shares Outstanding, beginning balance (in shares)	'	'	15,108	'
Granted (in shares)	'	'	9,324	'
Canceled / Forfeited (in shares)	'	'	-2,248	'
Nonvested Shares Outstanding, ending balance (in shares)	22,184	'	22,184	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'	'	'
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, Canceled / Forfeited (in dollars per share)	'	'	$50.02	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$50.80	'	$50.80	'
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	$0.40
Grant Date January 2011 - TSR [Member]	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'
Shares Outstanding (in shares)	7,116	'	7,116	'
Fair Value Per Share (in dollars per share)	$50.94	'	$50.94	'
Expected Volatility	'	'	27.50%	'
Risk-Free Interest Rate	'	'	1.01%	'
Shares [Roll Forward]	'	'	'	'
Nonvested Shares Outstanding, ending balance (in shares)	7,116	'	7,116	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'	'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$50.94	'	$50.94	'
Grant Date January 2012 - TSR [Member]	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'
Shares Outstanding (in shares)	3,533	'	3,533	'
Fair Value Per Share (in dollars per share)	$51.23	'	$51.23	'
Expected Volatility	'	'	22.50%	'
Risk-Free Interest Rate	'	'	0.43%	'
Shares [Roll Forward]	'	'	'	'
Nonvested Shares Outstanding, ending balance (in shares)	3,533	'	3,533	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'	'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$51.23	'	$51.23	'
Grant Date January 2012 - EPS [Member]	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'
Shares Outstanding (in shares)	3,533	'	3,533	'
Fair Value Per Share (in dollars per share)	$56.93	'	$56.93	'
Shares [Roll Forward]	'	'	'	'
Nonvested Shares Outstanding, ending balance (in shares)	3,533	'	3,533	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'	'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$56.93	'	$56.93	'
Grant Date January 2013 - TSR [Member]	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'
Shares Outstanding (in shares)	4,001	'	4,001	'
Fair Value Per Share (in dollars per share)	$44.38	'	$44.38	'
Expected Volatility	'	'	21.10%	'
Risk-Free Interest Rate	'	'	0.40%	'
Shares [Roll Forward]	'	'	'	'
Nonvested Shares Outstanding, ending balance (in shares)	4,001	'	4,001	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'	'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$44.38	'	$44.38	'
Grant Date January 2013 - EPS [Member]	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'
Shares Outstanding (in shares)	4,001	'	4,001	'
Fair Value Per Share (in dollars per share)	$51.18	'	$51.18	'
Shares [Roll Forward]	'	'	'	'
Nonvested Shares Outstanding, ending balance (in shares)	4,001	'	4,001	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'	'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$51.18	'	$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%	'

RATES_AND_REGULATORY_ACTIONS_D

RATES AND REGULATORY ACTIONS (Details) (USD $)	1 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Jun. 30, 2013	31-May-13	Feb. 28, 2013	Jan. 31, 2013	Oct. 31, 2012	Jul. 31, 2012
Public Utilities, General Disclosures [Abstract]	'	'	'	'	'	'	'
Cost requested to be recovered through EEP I, approved additional investment	'	'	'	'	$2.50	'	'
Cost requested to be recovered through EEP, revenue increase	'	24	'	'	'	'	'
BGSS refunds made to customers	'	'	'	'	9.4	'	'
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	'	'	'	141.2	'	'	250
Investment requested to be recovered through CIRT III, annual amount of AIRP	'	'	'	35.3	'	'	50
Petition to adjust BGSS and CIP, revenue decrease	'	'	17.9	'	'	'	'
Investment requested to be recovered through CIRT, revenue increase	'	'	15.5	'	'	13.2	'
Investment requested to be recovered through CIRT, investments to be rolled into base rate	'	'	6.9	'	'	110.6	'
CIRT investments	'	'	'	'	'	117.5	'
Costs requested for deferral, storm related	'	0.7	'	'	'	'	'
Investment requested to be recovered through SHARP	$280	'	'	'	'	'	'
Investment requested to be recovered through SHARP, term	'7 years	'	'	'	'	'	'

REGULATORY_ASSETS_AND_LIABILIT2

REGULATORY ASSETS AND LIABILITIES (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Regulatory Assets [Line Items]	'	'
Total regulatory assets	$326,727	$352,656
Environmental Restoration Costs: Expended - Net [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	30,189	37,892
Environmental Restoration Costs: Liability for Future Expenditures [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	108,236	107,410
Deferred Asset Retirement Obligation Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	30,607	30,199
Deferred Pension and Other Postretirement Benefit Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	95,897	95,897
Conservation Incentive Program Receivable [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	12,573	31,686
Societal Benefit Costs Receivable [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	12,816	12,801
Premium for Early Retirement of debt [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	976	1,075
Deferred Interest Rate Contracts [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	4,569	7,761
Energy Efficiency Tracker [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	12,263	12,306
Pipeline Supplier Service Charges [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	7,522	8,771
Other Regulatory Assets [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	$11,079	$6,858

REGULATORY_ASSETS_AND_LIABILIT3

REGULATORY ASSETS AND LIABILITIES REGULATORY ASSETS AND LIABILITIES 2 (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	$52,219	$56,517
Excess Plant Removal Costs [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	41,128	45,593
Deferred Revenues - Net [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	8,352	10,924
Other Regulatory Liabilities [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	$2,739	$0

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Related Party Transaction [Line Items]	'		'		'		'
Operating Revenues/Affiliates	$679		$523		$2,168		$982
Operations Expense/Affiliates	4,629		4,174		14,555		13,235
SJRG [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operating Revenues/Affiliates	344		211		1,194		483
Costs of Sales/Affiliates (Excluding depreciation)	5,436		2,683		11,105		8,445
Energy-Related Derivative (Gains) / Losses	389	[1]	3,011	[1]	568	[1]	13,666	[1]
SJI [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operations Expense/Affiliates	2,737		2,237		8,613		7,400
SJIS [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operations Expense/Affiliates	1,330		1,240		4,264		3,833
Millennium [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operations Expense/Affiliates	665		796		2,014		2,379
Other [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operating Revenues/Affiliates	335		312		974		499
Operations Expense/Affiliates	($103)		($99)		($336)		($377)
[1]	Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.

FINANCIAL_INSTRUMENTS_Details

FINANCIAL INSTRUMENTS (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Schedule of Financial Instruments [Line Items]	'	'
Restricted investments held in escrow	$0.10	$0.10
Margin accounts with selected counterparties to support risk management activities	0.9	1.1
Restricted investments, energy-related contracts	1	'
Estimated fair value of long-term debt	446.2	502
Carrying amount of long-term debt	425	450
Financing Receivable [Member]	'	'
Schedule of Financial Instruments [Line Items]	'	'
Long-term receivables, net of unamortized discount	14	13.6
Imputed interest	$1.30	$1.30

UNUSED_LINES_OF_CREDIT_Details

UNUSED LINES OF CREDIT (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Line of Credit Facility [Line Items]	'	'
Total Facility	$210,000,000	'
Usage	110,000,000	'
Available Liquidity	100,000,000	'
Average borrowings outstanding during the period	90,500,000	146,300,000
Maximum amounts outstanding during the period	119,900,000	180,500,000
Weighted average borrowing cost	0.34%	0.47%
Revolving Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Total Facility	200,000,000	'
Usage	110,000,000	'
Available Liquidity	90,000,000	'
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	'
Minimum [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Financial covenant, ratio of indebtedness to consolidated total capitalization minimum	0.65	'

PENSION_AND_OTHER_POSTRETIREME2

PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) (USD $)	1 Months Ended		3 Months Ended		9 Months Ended
	Jan. 31, 2013	Jan. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Pension Benefits [Member]	'	'	'	'	'	'
Net periodic benefit cost [Abstract]	'	'	'	'	'	'
Service cost	'	'	$1,040,000	$873,000	$3,120,000	$2,619,000
Interest cost	'	'	1,811,000	1,853,000	5,434,000	5,559,000
Expected return on plan assets	'	'	-2,286,000	-1,991,000	-6,859,000	-5,974,000
Amortizations [Abstract]	'	'	'	'	'	'
Prior service cost (credits)	'	'	48,000	48,000	144,000	145,000
Actuarial loss	'	'	1,729,000	1,469,000	5,185,000	4,407,000
Net periodic benefit cost prior to capitalized benefit costs	'	'	2,342,000	2,252,000	7,024,000	6,756,000
Capitalized benefit costs	'	'	-1,218,000	-1,306,000	-3,653,000	-3,513,000
Total net periodic benefit expense	'	'	1,124,000	946,000	3,371,000	3,243,000
Contributions	9,100,000	19,800,000	'	'	'	'
Other Postretirement Benefits [Member]	'	'	'	'	'	'
Net periodic benefit cost [Abstract]	'	'	'	'	'	'
Service cost	'	'	212,000	198,000	637,000	594,000
Interest cost	'	'	509,000	573,000	1,526,000	1,719,000
Expected return on plan assets	'	'	-443,000	-402,000	-1,329,000	-1,206,000
Amortizations [Abstract]	'	'	'	'	'	'
Prior service cost (credits)	'	'	-53,000	-54,000	-159,000	-162,000
Actuarial loss	'	'	324,000	329,000	972,000	988,000
Net periodic benefit cost prior to capitalized benefit costs	'	'	549,000	644,000	1,647,000	1,933,000
Capitalized benefit costs	'	'	-285,000	-374,000	-856,000	-1,005,000
Total net periodic benefit expense	'	'	264,000	270,000	791,000	928,000
Defined benefit plan regulatory obligation to contribute to the plan during the period	'	'	3,600,000	'	3,600,000	'
Supplemental Employee Retirement Plans, Defined Benefit [Member]	'	'	'	'	'	'
Amortizations [Abstract]	'	'	'	'	'	'
Estimated future contributions	'	'	$1,200,000	'	$1,200,000	'

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
	unions
	sites
Loss Contingencies [Line Items]	'	'
Letter of credit provided	$210,000,000	'
Number of sites for environmental cleanup	12	'
Monthly gas supply related demand charges and reservation fees	4,300,000	'
Estimated litigation liability	400,000	500,000
Percentage of personnel represented in collective bargaining agreements	60.00%	'
Number of unions	2	'
Standby Letter of Credit [Member]	'	'
Loss Contingencies [Line Items]	'	'
Letter of credit provided	$25,200,000	'

FAIR_VALUE_OF_FINANCIAL_ASSETS2

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) (USD $)

3 Months Ended

9 Months Ended

In Thousands, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Total [Member]

Total [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Assets [Abstract]

'

'

'

'

'

'

'

'

'

'

Available-for-sale Securities

'

'

$8,237

[1]

$7,520

[1]

$8,237

[1]

$769

[1]

$0

[1]

$6,751

[1]

$0

[1]

$0

[1]

Derivatives - Energy Related Assets

'

'

306

[2]

766

[2]

306

[2]

447

[2]

0

[2]

319

[2]

0

[2]

0

[2]

Total Assets

'

'

8,543

8,286

8,543

1,216

0

7,070

0

0

Liabilities [Abstract]

'

'

'

'

'

'

'

'

'

'

Derivatives - Energy Related Liabilities

'

'

1,785

[2]

2,695

[2]

1,466

[2]

2,694

[2]

0

[2]

1

[2]

319

[2]

0

[2]

Derivatives - Other

'

'

4,569

[3]

7,761

[3]

0

[3]

0

[3]

4,569

[3]

7,761

[3]

0

[3]

0

[3]

Total Liabilities

'

'

6,354

10,456

1,466

2,694

4,569

7,762

319

0

Changes in significant unobservable inputs [Roll forward]

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period

-243

0

'

'

'

'

'

'

'

'

Total losses unrealized in Regulatory Liabilities (see note 4)

-76

-319

'

'

'

'

'

'

'

'

Settlements

0

0

'

'

'

'

'

'

'

'

Total activity

-76

-319

'

'

'

'

'

'

'

'

Balance at end of period

($319)

($319)

'

'

'

'

'

'

'

'

[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 consisted of funds that are not publicly traded. These funds, which consisted 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. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

[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.

FAIR_VALUE_OF_FINANCIAL_ASSETS3

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES, LEVEL THREE INPUTS (Details) (Forward Contracts [Member], Level 3 [Member], Natural Gas (in MMdts) [Member], USD $)	Sep. 30, 2013
In Thousands, unless otherwise specified
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'
Assets	$0
Liabilities	$319
Minimum [Member]	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'
Forward price (in dollars per dt)	-1.75
Maximum [Member]	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'
Forward price (in dollars per dt)	-1.75
Weighted Average [Member]	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'
Forward price (in dollars per dt)	-1.75

DERIVATIVE_INSTRUMENTS_Details

DERIVATIVE INSTRUMENTS (Details) (USD $)

1 Months Ended

3 Months Ended

9 Months Ended

Sep. 30, 2005

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

South Jersey Resource Group [Member]

South Jersey Resource Group [Member]

South Jersey Resource Group [Member]

South Jersey Resource Group [Member]

Natural Gas (in MMdts) [Member]

Derivative Transaction Type, Purchase [Member]

millions_of_decatherms

Derivative [Line Items]

'

'

'

'

'

'

'

'

Outstanding derivative contracts notional amount

'

'

'

'

'

'

'

6.5

Unrealized gains (losses) included in its BGSS related to open financial contracts

'

$1,500,000

($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

'

'

'

'

'

Net realized losses associated with SJG's energy-related financial commodity contracts

'

'

'

$389,000

[1]

$3,011,000

[1]

$568,000

[1]

$13,666,000

[1]

'

[1]

Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.

DERIVATIVE_INSTRUMENTS_2_Detai

DERIVATIVE INSTRUMENTS 2 (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	$306	$766
Fair value Derivative Liabilities	6,354	10,456
Not Designated as Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	306	766
Fair value Derivative Liabilities	6,354	10,456
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-Current [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	239	464
Fair value Derivative Liabilities	1,606	2,615
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-NonCurrent [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	67	302
Fair value Derivative Liabilities	179	80
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$4,569	$7,761

DERIVATIVE_INSTRUMENTS_DERIVAT

DERIVATIVE INSTRUMENTS DERIVATIVE INSTRUMENTS 3 (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Commodity Contract [Member]	'		'
Offsetting Derivative Assets [Abstract]	'		'
Gross amounts of recognized assets/liabilities	$306		$766
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	306		766
Gross amounts not offset in the balance sheet, Financial Instruments	-306	[1]	-447	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		0
Net amount	0		319
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-1,785		-2,695
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-1,785		-2,695
Gross amounts not offset in the balance sheet, Financial Instruments	306	[2]	447	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	1,160		1,136
Net amount	-319		-1,112
Interest Rate Contract [Member]	'		'
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-4,569		-7,761
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-4,569		-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	($4,569)		($7,761)
[1]	The balances at September 30, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at September 30, 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 $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'		'		'		'
Losses reclassified from accumulated OCI into income	($12)	[1]	($12)	[1]	($36)	[1]	($36)	[1]
[1]	Included in Interest Charges

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (Medium-term Notes [Member], USD $)	1 Months Ended			3 Months Ended
	Sep. 30, 2013	Feb. 28, 2012	Apr. 30, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013
		Series Due 2027, 7.7 Percent [Member]	Series Due 2032, 3.74 Percent [Member]	Series Due 2013, 4.46 Percent [Member]	Series Due 2013, 5.027 Percent [Member]	Series Due 2030, 4.01 Percent [Member]	Series Due 2030, 4.23 Percent [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'
Debt called	'	$35,000,000	'	$10,500,000	$14,500,000	'	'
Stated interest rate	'	7.70%	3.74%	4.46%	5.03%	4.00%	4.20%
Premium in addition to par for called debt	'	2.00%	'	'	'	'	'
Debt issued	'	'	35,000,000	'	'	50,000,000	30,000,000
Debt planned for future issuance	$80,000,000	'	'	'	'	'	'

ACCUMULATED_OTHER_COMPREHENSIV2

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	($13,568)	[1]	'		($13,285)	[1]	'
Other comprehensive income before reclassifications	221		'		413		'
Amounts reclassified from AOCL	7	[2]	'		-468	[2]	'
Other Comprehensive (Loss) Gain - Net of Tax	228	[1]	212	[1]	-55	[1]	441	[1]
Ending balance	-13,340	[1]	'		-13,340	[1]	'
Combined statutory tax rate	41.00%		41.00%		41.00%		41.00%
Postretirement Liability Adjustment [Member]	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	-12,958	[1]	'		-12,958	[1]	'
Other comprehensive income before reclassifications	0		'		0		'
Amounts reclassified from AOCL	0	[2]	'		0	[2]	'
Other Comprehensive (Loss) Gain - Net of Tax	0		'		0		'
Ending balance	-12,958	[1]	'		-12,958	[1]	'
Unrealized Gain (Loss) on Derivatives-Other [Member]	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	-607	[1]	'		-621	[1]	'
Other comprehensive income before reclassifications	0		'		0		'
Amounts reclassified from AOCL	7	[2]	'		21	[2]	'
Other Comprehensive (Loss) Gain - Net of Tax	7		'		21		'
Ending balance	-600	[1]	'		-600	[1]	'
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	-3	[1]	'		294	[1]	'
Other comprehensive income before reclassifications	221		'		413		'
Amounts reclassified from AOCL	0	[2]	'		-489	[2]	'
Other Comprehensive (Loss) Gain - Net of Tax	221		'		-76		'
Ending balance	$218	[1]	'		$218	[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			9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Interest Charges	($2,629)		($3,872)	($8,379)		($11,832)
Other Income and Expense	764		1,703	3,024		4,482
Income Before Income Taxes	1,420		781	63,794		61,920
Income Taxes	-471		-258	-23,511		-23,122
Net Income	949		523	40,283		38,798
Reclassification out of Accumulated Other Comprehensive Income [Member]	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Income Before Income Taxes	12		'	-792		'
Income Taxes	-5	[1]	'	324	[1]	'
Net Income	7		'	-468		'
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Gain (Loss) on Derivatives-Other [Member]	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Interest Charges	12		'	36		'
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Gain (Loss) on Available-for-Sale Securities [Member]	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Other Income and Expense	$0		'	($828)		'
[1]	Determined using a combined statutory tax rate of 41% .

EQUITY_CONTRIBUTIONS_Details

EQUITY CONTRIBUTIONS (Details) (USD $)	1 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012
Equity [Abstract]	'	'	'
Additional Investment from SJI	$25,000	$25,000	$0

SUBSEQUENT_EVENT_Details

SUBSEQUENT EVENT (Details) (Subsequent Event [Member], USD $)	1 Months Ended
	Oct. 31, 2013
Subsequent Event [Line Items]	'
Amount of additional debt petitioned for, period	'3 years
Maximum [Member]	'
Subsequent Event [Line Items]	'
Amount of additional debt petitioned for	200,000,000