SOUTH JERSEY GAS 10-Q 9 May 14 2014 Q1 Quarterly report Financial data

DOCUMENT_AND_ENTITY_INFORMATIO

DOCUMENT AND ENTITY INFORMATION Document	3 Months Ended
	Mar. 31, 2014	1-May-14
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	31-Mar-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q1	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	2,339,139

CONDENSED_STATEMENTS_OF_INCOME

CONDENSED STATEMENTS OF INCOME (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Income Statement [Abstract]	'	'
Operating Revenues	$210,545	$174,098
Operating Expenses:	'	'
Cost of Sales (Excluding depreciation)	103,293	77,602
Operations	30,312	24,051
Maintenance	3,259	3,422
Depreciation	9,056	8,225
Energy and Other Taxes	1,185	3,003
Total Operating Expenses	147,105	116,303
Operating Income	63,440	57,795
Other Income and Expense	1,086	1,450
Interest Charges	-4,342	-2,961
Income Before Income Taxes	60,184	56,284
Income Taxes	-22,527	-20,771
Net Income	$37,657	$35,513

CONDENSED_STATEMENTS_OF_COMPRE

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Statement of Other Comprehensive Income [Abstract]	'		'
Net Income	$37,657		$35,513
Other Comprehensive Gain (Loss) - Net of Tax:	'		'
Unrealized Gain (Loss) on Available-for-Sale Securities	62	[1]	-274	[1]
Unrealized Gain on Derivatives - Other	8	[1]	7	[1]
Other Comprehensive Gain (Loss) - Net of Tax	70	[1]	-267	[1]
Comprehensive Income	$37,727		$35,246
[1]	Determined using a combined statutory tax rate of 41% .

CONDENSED_STATEMENTS_OF_COMPRE1

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Statement of Other Comprehensive Income [Abstract]	'	'
Combined statutory tax rate	41.00%	41.00%

CONDENSED_STATEMENTS_OF_CASH_F

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Statement of Cash Flows [Abstract]	'	'
Net Cash Provided by Operating Activities	$31,553	$55,766
Cash Flows from Investing Activities:	'	'
Capital Expenditures	-40,674	-25,718
Net Purchase of Restricted Investments in Margin Accounts	-463	-862
Investment in Long-Term Receivables	-2,053	-1,947
Proceeds from Long-Term Receivables	1,981	2,402
Net Cash Used in Investing Activities	-41,209	-26,125
Cash Flows from Financing Activities:	'	'
Net Repayments of Short-Term Credit Facilities	-17,800	-31,500
Proceeds from Issuance of Long-Term Debt	30,000	0
Payments for Issuance of Long-Term Debt	-210	-11
Net Cash Provided by (Used in) Financing Activities	11,990	-31,511
Net Increase (Decrease) in Cash and Cash Equivalents	2,334	-1,870
Cash and Cash Equivalents at Beginning of Period	2,020	2,678
Cash and Cash Equivalents at End of Period	$4,354	$808

CONDENSED_BALANCE_SHEETS_UNAUD

CONDENSED BALANCE SHEETS (UNAUDITED) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment:	'		'
Utility Plant, at original cost	$1,846,704		$1,816,804
Accumulated Depreciation	-398,954		-392,029
Property, Plant and Equipment - Net	1,447,750		1,424,775
Investments:	'		'
Available-for-Sale Securities	8,808		8,696
Restricted Investments	1,143		680
Total Investments	9,951		9,376
Current Assets:	'		'
Cash and Cash Equivalents	4,354		2,020
Accounts Receivable	124,733		60,317
Accounts Receivable - Related Parties	1,504		968
Unbilled Revenues	40,149		41,510
Provision for Uncollectibles	-5,425		-4,553
Natural Gas in Storage, average cost	5,228		20,811
Materials and Supplies, average cost	1,801		1,798
Deferred Income Taxes - Net	3,728		23,309
Prepaid Taxes	0		7,683
Derivatives - Energy Related Assets	2,121		1,222
Other Prepayments and Current Assets	3,604		3,819
Total Current Assets	181,797		158,904
Regulatory and Other Noncurrent Assets:	'		'
Regulatory Assets	309,290		296,081
Unamortized Debt Issuance Costs	7,523		6,523
Long-Term Receivables	10,292		10,252
Derivatives - Energy Related Assets	69		278
Other	3,001		2,937
Total Regulatory and Other Noncurrent Assets	330,175		316,071
Total Assets	1,969,673		1,909,126
Common Equity:	'		'
Common Stock, Par Value $2.50 per share: Authorized - 4,000,000 shares Outstanding - 2,339,139 shares	5,848		5,848
Other Paid-In Capital and Premium on Common Stock	225,972		225,972
Accumulated Other Comprehensive Loss	-10,799	[1]	-10,869	[1]
Retained Earnings	427,675		390,018
Total Common Equity	648,696		610,969
Long-Term Debt	484,000		454,000
Total Capitalization	1,132,696		1,064,969
Current Liabilities:	'		'
Notes Payable	47,700		65,500
Current Portion of Long-Term Debt	21,000		21,000
Accounts Payable - Commodity	35,465		24,232
Accounts Payable - Other	35,900		32,072
Accounts Payable - Related Parties	9,761		6,638
Derivatives - Energy Related Liabilities	280		711
Customer Deposits and Credit Balances	14,016		15,089
Environmental Remediation Costs	25,412		15,422
Taxes Accrued	8,582		1,767
Pension Benefits	1,241		1,241
Interest Accrued	5,163		6,039
Other Current Liabilities	4,132		5,629
Total Current Liabilities	208,652		195,340
Regulatory and Other Noncurrent Liabilities:	'		'
Regulatory Liabilities	48,158		60,949
Deferred Income Taxes - Net	381,494		380,975
Environmental Remediation Costs	94,192		104,070
Asset Retirement Obligations	41,412		41,178
Pension and Other Postretirement Benefits	49,380		48,197
Investment Tax Credits	307		360
Derivatives - Energy Related Liabilities	186		48
Derivatives - Other	4,735		3,735
Other	8,461		9,305
Total Regulatory and Other Noncurrent Liabilities	628,325		648,817
Commitments and Contingencies (Note 9)	'		'
Total Capitalization and Liabilities	$1,969,673		$1,909,126
[1]	Determined using a combined statutory tax rate of 41% .

CONDENSED_BALANCE_SHEETS_UNAUD1

CONDENSED BALANCE SHEETS (UNAUDITED) (Parenthetical) (USD $)	Mar. 31, 2014	Dec. 31, 2013
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	3 Months Ended
	Mar. 31, 2014
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 2013 Form 10-K for a more complete discussion of our accounting policies and certain other information.
	Certain reclassifications have been made to the prior periods regulatory assets disclosure to conform to the current period presentation. The deferred pipeline integrity cost and allowance for funds used during construction (AFUDC) - equity related deferrals previously included in "Other Regulatory Assets" were reclassified to the line items "Pipeline Integrity Cost" and "AFUDC - Equity Related Deferrals", respectively, in the regulatory asset table disclosed in Note 4.
	REVENUE AND THROUGHPUT - BASED TAXES - SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. The PUA is included in both revenues and cost of sales, and totaled $0.4 million and $0.4 million for the three months ended March 31, 2014 and 2013, respectively.In prior years, SJG had collected a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). The TEFA was eliminated effective January 1, 2014.
	NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2014 or 2013 had, or is expected to have, a material impact on the condensed financial statements.
	In July 2013, the FASB issued Accounting Standard Update (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. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance did not have an impact on the Company's financial statement results.

STOCKBASED_COMPENSATION_PLANS

STOCK-BASED COMPENSATION PLANS	3 Months Ended
	Mar. 31, 2014
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 use SJI's total shareholder return (TSR) relative to a peer group to measure performance. Grants containing earnings-based targets 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, 2013 for the related accounting policy.
	The following table summarizes the SJI nonvested restricted stock awards pertaining to SJG outstanding at March 31, 2014, and the assumptions used to estimate the fair value of the awards:
	Grant Date		Shares		Fair Value		Expected		Risk-Free
			Outstanding		Per Share		Volatility		Interest Rate
	Jan. 2012 - TSR		3,533		$	51.23	22.5	%	0.43	%
	Jan. 2012 - EPS		3,533		$	56.93	n/a		n/a
	Jan. 2013 - TSR		4,001		$	44.38	21.1	%	0.4	%
	Jan. 2013 - EPS		4,001		$	51.18	n/a		n/a
	Jan. 2014 - TSR		5,197		$	44.32	20	%	0.8	%
	Jan. 2014 - EPS		5,197		$	54.44	n/a		n/a
	Expected volatility is based on the actual volatility of SJI’s share price over the preceding three year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three year term of the restricted shares. As notional dividend equivalents are credited to the holders during the three year service period, no reduction to the fair value of the award is required.
	The cost for restricted stock awards during 2014 and 2013 is approximately $0.1 million per quarter.
	As of March 31, 2014, there was $0.8 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 2.2 years.
	The following table summarizes information regarding restricted stock award activity during the three months ended March 31, 2014, excluding accrued dividend equivalents:
		Shares		Weighted
				Average
				Grant Date
				Fair Value
	Nonvested Shares Outstanding, January 1, 2014	15,068		$	50.73
	Granted	10,394		$	49.38
	Nonvested Shares Outstanding, March 31, 2014	25,462		$	50.18
	Performance targets during the three-year vesting period were not attained for the January 2011 grant that had vested at December 31, 2013. As a result, no shares were awarded in 2014. During the three months ended March 31, 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. 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 three months ended March 31, 2014 and 2013 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	3 Months Ended
	Mar. 31, 2014
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 November 2013, we filed a base rate case with the BPU to increase our base rates to obtain a certain level of return on our capital investments. In March 2014, we filed an update to the original filing and expect the base rate case to be concluded during 2014.
	In January 2014, SJG credited the accounts of our periodic Basic Gas Supply Service (BGSS) customers with refunds totaling $11.2 million based on a projected over collection, at that time, due to lower gas costs.
	There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2013. See Note 3 to the Financial Statements in Item 8 of SJG's Form 10-K as of December 31, 2013.

REGULATORY_ASSETS_AND_LIABILIT

REGULATORY ASSETS AND LIABILITIES	3 Months Ended
	Mar. 31, 2014
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, 2013, 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, 2013.
	Regulatory Assets consisted of the following items (in thousands):
		March 31, 2014		December 31, 2013
	Environmental Remediation Costs:
	Expended - Net	$	26,590	$	29,945
	Liability for Future Expenditures	119,604		119,492
	Deferred Asset Retirement Obligation Costs	31,347		31,142
	Deferred Pension and Other Postretirement Benefit Costs	59,284		59,284
	Deferred Gas Costs - Net	34,008		—
	Conservation Incentive Program Receivable	—		10,526
	Societal Benefit Costs Receivable	5,528		10,408
	Premium for Early Retirement of Debt	—		955
	Deferred Interest Rate Contracts (Note 11)	4,735		3,735
	Energy Efficiency Tracker	7,470		10,420
	Pipeline Supplier Service Charges	6,690		7,106
	Pipeline Integrity Cost	2,962		2,902
	AFUDC - Equity Related Deferrals	8,631		7,810
	Other Regulatory Assets	2,441		2,356
	Total Regulatory Assets	$	309,290	$	296,081
	DEFERRED GAS COSTS - NET - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. The change from a $19.1 million regulatory liability at December 31, 2013 to a $34.0 million regulatory asset at March 31, 2014 was due to the actual cost of the commodity incurred during the first quarter exceeding the gas costs recovered from the customers as a result of higher prices.
	CONSERVATION INCENTIVE PROGRAM (CIP) RECEIVABLE – The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. Actual usage per customer was greater than the established baseline during the first three months of 2014 resulting in a payable that is recorded in the table below as a regulatory liability.The change from a receivable to a related payable is primarily the result of colder weather experienced in the region during the first quarter of 2014.
	SOCIETAL BENEFIT COSTS RECEIVABLE - This regulatory asset primarily represents the deferred expenses under the New Jersey Clean Energy Program which is a mechanism designed to recover costs associated with energy efficiency and renewable energy programs. The decrease in the asset is due to colder weather experienced in the region during the first quarter of 2014 resulting in increased recoveries of the deferred expense.
	Regulatory Liabilities consisted of the following items (in thousands):
		March 31, 2014		December 31, 2013
	Excess Plant Removal Costs	$	39,647	$	40,029
	Deferred Revenues-Net	—		19,067
	Conservation Incentive Program Payable	6,193		—
	Other Regulatory Liabilities	2,318		1,853
	Total Regulatory Liabilities	$	48,158	$	60,949
	DEFERRED REVENUES - NET - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. See "Deferred Gas -Costs - Net" above.
	CONSERVATION INCENTIVE PROGRAM PAYABLE – The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. See "Conservation Incentive Program (CIP) Receivable" above.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	3 Months Ended
	Mar. 31, 2014
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, 2013. See Note 5 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2013 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
		March 31,
		2014			2013
	Operating Revenues/Affiliates:
	SJRG	$	158		$	387
	Marina	333			321
	Other	—			1
	Total Operating Revenue/Affiliates	$	491		$	709
	Related party transactions, excluding pass-through items, included in Operating Expenses were as follows, (in thousands):
		Three Months Ended
		March 31,
		2014			2013
	Costs of Sales/Affiliates (Excluding depreciation):
	SJRG	$	5,484		$	911
	Energy-Related Derivative (Gains) / Losses *
	SJRG	$	(1,030	)	$	1,457
	* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.
	Operations Expense/Affiliates
	SJI	$	4,030		$	2,922
	SJIS	—			1,555
	Millennium	608			674
	Other	(104		)	(128		)
	Total Operations Expense/Affiliates	$	4,534		$	5,023

FINANCIAL_INSTRUMENTS

FINANCIAL INSTRUMENTS	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014 and December 31, 2013, 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 March 31, 2014 and December 31, 2013, the balance held with SJRG totaled $0.8 million and $0.5 million, respectively. SJG also established a margin account with another 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 March 31, 2014 the balance held with this counterparty totaled $0.2 million. There was no balance held with this counterparty as of December 31, 2013. The carrying amounts of the Restricted Investments approximate their fair value at March 31, 2014 and December 31, 2013, which would be included in Level 1 of the fair value hierarchy. (See Note 10 - Fair Value of Financial Assets and Financial Liabilities).
	LONG-TERM RECEIVABLES – SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources.  The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest.  The carrying amounts of such loans were $15.0 million as of both March 31, 2014 and December 31, 2013.  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 March 31, 2014 and December 31, 2013.  The annual amortization to interest is not material to SJG’s financial statements.  The carrying amounts of these receivables approximate their fair value at March 31, 2014 and December 31, 2013, 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 March 31, 2014 and December 31, 2013, 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 March 31, 2014 and December 31, 2013, were $531.3 million and $486.5 million, respectively.  The carrying amounts of SJG's long-term debt, including current maturities, as of March 31, 2014 and December 31, 2013 were $505.0 million and $475.0 million respectively.

LINES_OF_CREDIT

LINES OF CREDIT	3 Months Ended
	Mar. 31, 2014
Line of Credit Facility [Abstract]	'
LINES OF CREDIT	'
	LINES OF CREDIT:
	Credit facilities and available liquidity as of March 31, 2014 were as follows (in thousands):
		Total Facility		Usage		Available Liquidity		Expiration Date
	Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	47,700	$	152,300	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total	$	210,000	$	47,700	$	162,300
	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 March 31, 2014.
	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 three months ended March 31, 2014 and 2013 were $40.8 million and $86.2 million, respectively.  The maximum amount outstanding under these credit facilities during the three months ended March 31, 2014 and 2013 were $66.0 million and $103.0 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 0.25% and 0.44% at March 31, 2014 and 2013, respectively.

PENSION_AND_OTHER_POSTRETIREME

PENSION AND OTHER POSTRETIREMENT BENEFITS	3 Months Ended
	Mar. 31, 2014
Compensation and Retirement Disclosure [Abstract]	'
PENSION AND OTHER POSTRETIREMENT BENEFITS	'
	PENSION AND OTHER POSTRETIREMENT BENEFITS:
	For the three months ended  March 31, 2014 and 2013, 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
		Three Months Ended
		March 31,
		2014			2013
	Service Cost	$	966		$	1,047
	Interest Cost	2,027			1,772
	Expected Return on Plan Assets	(2,455		)	(2,271		)
	Amortizations:
	Prior Service Cost	33			48
	Actuarial Loss	1,072			1,649
	Net Periodic Benefit Cost	1,643			2,245
	Capitalized Benefit Costs	(854		)	(1,167		)
	Total Net Periodic Benefit Expense	$	789		$	1,078
		Other Postretirement Benefits
		Three Months Ended
		March 31,
		2014			2013
	Service Cost	$	172		$	238
	Interest Cost	510			535
	Expected Return on Plan Assets	(473		)	(449		)
	Amortizations:
	Prior Service Cost (Credits)	26			(54		)
	Actuarial Loss	167			351
	Net Periodic Benefit Cost	402			621
	Capitalized Benefit Costs	(209		)	(322		)
	Total Net Periodic Benefit Expense	$	193		$	299
	Capitalized benefit costs reflected in the table above relate to our construction program.
	SJG contributed $9.1 million to the pension plans in January 2013. No contributions are expected to be made to the pension plans during 2014. Payments related to the unfunded Supplemental Executive Retirement Plan (SERP) are expected to approximate $1.2 million in 2014. 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, 2013 for additional information related to SJG’s pension and other postretirement benefits.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 2014
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, 2013, as described in Note 12 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2013.
	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 March 2015. 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 $4.1 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 March 31, 2014 and December 31, 2013, 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 March 31, 2014. 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 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	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014
		Total		Level 1		Level 2		Level 3
	Assets -
	Available-for-Sale Securities (A)	$	8,808	$	8,808	$	—	$	—
	Derivatives – Energy Related Assets (B)	2,190		2,190		—		—
		$	10,998	$	10,998	$	—	$	—
	Liabilities -
	Derivatives – Energy Related Liabilities (B)	$	466	$	466	$	—	$	—
	Derivatives – Other (C)	4,735		—		4,735		—
		$	5,201	$	466	$	4,735	$	—
	As of December 31, 2013
		Total		Level 1		Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,696	$	8,696	$	—	$	—
	Derivatives - Energy Related Assets (B)	1,500		1,409		91		—
		$	10,196	$	10,105	$	91	$	—
	Liabilities
	Derivatives - Energy Related Liabilities (B)	$	759	$	155	$	604	$	—
	Derivatives - Other (C)	3,735		—		3,735		—
		$	4,494	$	155	$	4,339	$	—
	(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.

DERIVATIVE_INSTRUMENTS

DERIVATIVE INSTRUMENTS	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014, SJG had outstanding derivative contracts intended to limit the exposure to market risk on 11.8 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 March 31, 2014 and December 31, 2013, SJG had $1.7 million and $0.7 million of unrealized gains, 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, 2013 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, 2013. 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 both March 31, 2014 and December 31, 2013, the unamortized balance was approximately $1.0 million .
	The fair values of all derivative instruments, as reflected in the condensed balance sheets as of March 31, 2014 and December 31, 2013, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	March 31, 2014						December 31, 2013
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	2,121		$	280		$	1,222		$	711
	Derivatives – Energy Related – Non-Current	69			186			278			48
	Interest rate contracts:
	Derivatives – Other	—			4,735			—			3,735
	Total derivatives not designated as hedging instruments under GAAP	2,190			5,201			1,500			4,494
	Total Derivatives	$	2,190		$	5,201		$	1,500		$	4,494
	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 March 31, 2014
	Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet			Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
											Financial Instruments				Cash Collateral Posted
	Derivatives - Energy Related Assets	$	2,190		$	—		$	2,190		$	(466	)	(A)	$	—		$	1,724
	Derivatives - Energy Related Liabilities	(466		)	—			(466		)	466			(B)	—			—
	Derivatives - Other	(4,735		)	—			(4,735		)	—				—			(4,735		)
	As of December 31, 2013
	Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet			Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
											Financial Instruments				Cash Collateral Posted
	Derivatives - Energy Related Assets	$	1,500		$	—		$	1,500		$	(155	)	(A)	$	(498	)	$	847
	Derivatives - Energy Related Liabilities	(759		)	—			(759		)	155			(B)	—			(604		)
	Derivatives - Other	(3,735		)	—			(3,735		)	—				—			(3,735		)
	(A) The balances at March 31, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at March 31, 2013 and December 31, 2013 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 months ended March 31, 2014 and 2013 are as follows (in thousands):
		Three months ended
		March 31,
	Derivatives in Cash Flow Hedging Relationships	2014			2013
	Interest Rate Contracts:
	Losses reclassified from Accumulated Other Comprehensive Loss into income (a)	$	(12	)	$	(12	)
	(a) Included in Interest Charges
	Net realized gain of $2.4 million and loss of $1.5 million associated with SJG's energy related financial commodity contracts for the three months ended March 31, 2014 and 2013, respectively, are not included in the above table.  These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy related financial commodity contracts are deferred in Regulatory Assets or Liabilities and there is no impact to earnings.

LONGTERM_DEBT

LONG-TERM DEBT	3 Months Ended
	Mar. 31, 2014
Long-term Debt, Unclassified [Abstract]	'
LONG-TERM DEBT	'
	LONG-TERM DEBT:
	In January 2014, SJG issued $30.0 million aggregate principal amount of 4.23% Medium Term Notes (MTN's) 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.

ACCUMULATED_OTHER_COMPREHENSIV

ACCUMULATED OTHER COMPREHENSIVE LOSS	3 Months Ended
	Mar. 31, 2014
Equity [Abstract]	'
ACCUMULATED OTHER COMPREHENSIVE LOSS	'
	ACCUMULATED OTHER COMPREHENSIVE LOSS:
	The changes in Accumulated Other Comprehensive Loss (AOCL) for the three months ended March 31, 2014 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 January 1, 2014 (a)	$	(10,672	)	$	(594	)	$	397	$	(10,869	)
	Other comprehensive income before reclassifications	—			—			62		62
	Amounts reclassified from AOCL (b)	—			8			—		8
	Net current period other comprehensive income	—			8			62		70
	Balance at March 31, 2014 (a)	$	(10,672	)	$	(586	)	$	459	$	(10,799	)
	(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 months ended March 31, 2014 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
		31-Mar-14
	Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		Interest Charges
	Unrealized Gain on Available-for-Sale Securities	—			Other Income & Expense
		12			Loss (Income) Before Income Taxes
	Income Taxes (a)	4			Income Taxes (a)
	Losses (Gains) from reclassifications for the period net of tax	$	8
	(a) Determined using a combined statutory tax rate of 41%.

SUBSEQUENT_EVENT

SUBSEQUENT EVENT	3 Months Ended
	Mar. 31, 2014
Subsequent Events [Abstract]	'
SUBSEQUENT EVENT	'
	SUBSEQUENT EVENT:
	In April 2014, SJG received an equity infusion of $12.0 million from SJI.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
	Mar. 31, 2014
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). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses.
NEW ACCOUNTING PRONOUNCEMENTS	'
	NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2014 or 2013 had, or is expected to have, a material impact on the condensed financial statements.
	In July 2013, the FASB issued Accounting Standard Update (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. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance did not 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)	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014, and the assumptions used to estimate the fair value of the awards:
	Grant Date		Shares		Fair Value		Expected		Risk-Free
			Outstanding		Per Share		Volatility		Interest Rate
	Jan. 2012 - TSR		3,533		$	51.23	22.5	%	0.43	%
	Jan. 2012 - EPS		3,533		$	56.93	n/a		n/a
	Jan. 2013 - TSR		4,001		$	44.38	21.1	%	0.4	%
	Jan. 2013 - EPS		4,001		$	51.18	n/a		n/a
	Jan. 2014 - TSR		5,197		$	44.32	20	%	0.8	%
	Jan. 2014 - EPS		5,197		$	54.44	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 three months ended March 31, 2014, excluding accrued dividend equivalents:
		Shares		Weighted
				Average
				Grant Date
				Fair Value
	Nonvested Shares Outstanding, January 1, 2014	15,068		$	50.73
	Granted	10,394		$	49.38
	Nonvested Shares Outstanding, March 31, 2014	25,462		$	50.18

REGULATORY_ASSETS_AND_LIABILIT1

REGULATORY ASSETS AND LIABILITIES (Tables)	3 Months Ended
	Mar. 31, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Schedule of Regulatory Assets	'
	Regulatory Assets consisted of the following items (in thousands):
		March 31, 2014		December 31, 2013
	Environmental Remediation Costs:
	Expended - Net	$	26,590	$	29,945
	Liability for Future Expenditures	119,604		119,492
	Deferred Asset Retirement Obligation Costs	31,347		31,142
	Deferred Pension and Other Postretirement Benefit Costs	59,284		59,284
	Deferred Gas Costs - Net	34,008		—
	Conservation Incentive Program Receivable	—		10,526
	Societal Benefit Costs Receivable	5,528		10,408
	Premium for Early Retirement of Debt	—		955
	Deferred Interest Rate Contracts (Note 11)	4,735		3,735
	Energy Efficiency Tracker	7,470		10,420
	Pipeline Supplier Service Charges	6,690		7,106
	Pipeline Integrity Cost	2,962		2,902
	AFUDC - Equity Related Deferrals	8,631		7,810
	Other Regulatory Assets	2,441		2,356
	Total Regulatory Assets	$	309,290	$	296,081
Schedule of Regulatory Liabilities	'
	Regulatory Liabilities consisted of the following items (in thousands):
		March 31, 2014		December 31, 2013
	Excess Plant Removal Costs	$	39,647	$	40,029
	Deferred Revenues-Net	—		19,067
	Conservation Incentive Program Payable	6,193		—
	Other Regulatory Liabilities	2,318		1,853
	Total Regulatory Liabilities	$	48,158	$	60,949

RELATED_PARTY_TRANSACTIONS_Tab

RELATED PARTY TRANSACTIONS (Tables)	3 Months Ended
	Mar. 31, 2014
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
		March 31,
		2014			2013
	Operating Revenues/Affiliates:
	SJRG	$	158		$	387
	Marina	333			321
	Other	—			1
	Total Operating Revenue/Affiliates	$	491		$	709
	Related party transactions, excluding pass-through items, included in Operating Expenses were as follows, (in thousands):
		Three Months Ended
		March 31,
		2014			2013
	Costs of Sales/Affiliates (Excluding depreciation):
	SJRG	$	5,484		$	911
	Energy-Related Derivative (Gains) / Losses *
	SJRG	$	(1,030	)	$	1,457
	* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.
	Operations Expense/Affiliates
	SJI	$	4,030		$	2,922
	SJIS	—			1,555
	Millennium	608			674
	Other	(104		)	(128		)
	Total Operations Expense/Affiliates	$	4,534		$	5,023

LINES_OF_CREDIT_Tables

LINES OF CREDIT (Tables)	3 Months Ended
	Mar. 31, 2014
Line of Credit Facility [Abstract]	'
Schedule of lines of credit	'
	Credit facilities and available liquidity as of March 31, 2014 were as follows (in thousands):
		Total Facility		Usage		Available Liquidity		Expiration Date
	Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	47,700	$	152,300	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total	$	210,000	$	47,700	$	162,300

PENSION_AND_OTHER_POSTRETIREME1

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	3 Months Ended
	Mar. 31, 2014
Compensation and Retirement Disclosure [Abstract]	'
Schedule of defined benefit plans disclosures	'
	For the three months ended  March 31, 2014 and 2013, 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
		Three Months Ended
		March 31,
		2014			2013
	Service Cost	$	966		$	1,047
	Interest Cost	2,027			1,772
	Expected Return on Plan Assets	(2,455		)	(2,271		)
	Amortizations:
	Prior Service Cost	33			48
	Actuarial Loss	1,072			1,649
	Net Periodic Benefit Cost	1,643			2,245
	Capitalized Benefit Costs	(854		)	(1,167		)
	Total Net Periodic Benefit Expense	$	789		$	1,078
		Other Postretirement Benefits
		Three Months Ended
		March 31,
		2014			2013
	Service Cost	$	172		$	238
	Interest Cost	510			535
	Expected Return on Plan Assets	(473		)	(449		)
	Amortizations:
	Prior Service Cost (Credits)	26			(54		)
	Actuarial Loss	167			351
	Net Periodic Benefit Cost	402			621
	Capitalized Benefit Costs	(209		)	(322		)
	Total Net Periodic Benefit Expense	$	193		$	299

FAIR_VALUE_OF_FINANCIAL_ASSETS1

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014
		Total		Level 1		Level 2		Level 3
	Assets -
	Available-for-Sale Securities (A)	$	8,808	$	8,808	$	—	$	—
	Derivatives – Energy Related Assets (B)	2,190		2,190		—		—
		$	10,998	$	10,998	$	—	$	—
	Liabilities -
	Derivatives – Energy Related Liabilities (B)	$	466	$	466	$	—	$	—
	Derivatives – Other (C)	4,735		—		4,735		—
		$	5,201	$	466	$	4,735	$	—
	As of December 31, 2013
		Total		Level 1		Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,696	$	8,696	$	—	$	—
	Derivatives - Energy Related Assets (B)	1,500		1,409		91		—
		$	10,196	$	10,105	$	91	$	—
	Liabilities
	Derivatives - Energy Related Liabilities (B)	$	759	$	155	$	604	$	—
	Derivatives - Other (C)	3,735		—		3,735		—
		$	4,494	$	155	$	4,339	$	—
	(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.

DERIVATIVE_INSTRUMENTS_Tables

DERIVATIVE INSTRUMENTS (Tables)	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014 and December 31, 2013, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	March 31, 2014						December 31, 2013
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	2,121		$	280		$	1,222		$	711
	Derivatives – Energy Related – Non-Current	69			186			278			48
	Interest rate contracts:
	Derivatives – Other	—			4,735			—			3,735
	Total derivatives not designated as hedging instruments under GAAP	2,190			5,201			1,500			4,494
	Total Derivatives	$	2,190		$	5,201		$	1,500		$	4,494
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 March 31, 2014
	Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet			Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
											Financial Instruments				Cash Collateral Posted
	Derivatives - Energy Related Assets	$	2,190		$	—		$	2,190		$	(466	)	(A)	$	—		$	1,724
	Derivatives - Energy Related Liabilities	(466		)	—			(466		)	466			(B)	—			—
	Derivatives - Other	(4,735		)	—			(4,735		)	—				—			(4,735		)
	As of December 31, 2013
	Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet			Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
											Financial Instruments				Cash Collateral Posted
	Derivatives - Energy Related Assets	$	1,500		$	—		$	1,500		$	(155	)	(A)	$	(498	)	$	847
	Derivatives - Energy Related Liabilities	(759		)	—			(759		)	155			(B)	—			(604		)
	Derivatives - Other	(3,735		)	—			(3,735		)	—				—			(3,735		)
	(A) The balances at March 31, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at March 31, 2013 and December 31, 2013 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 months ended March 31, 2014 and 2013 are as follows (in thousands):
		Three months ended
		March 31,
	Derivatives in Cash Flow Hedging Relationships	2014			2013
	Interest Rate Contracts:
	Losses reclassified from Accumulated Other Comprehensive Loss into income (a)	$	(12	)	$	(12	)
	(a) Included in Interest Charges

ACCUMULATED_OTHER_COMPREHENSIV1

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	3 Months Ended
	Mar. 31, 2014
Equity [Abstract]	'
Schedule of changes in accumulated other comprehensive loss (AOCL)	'
	The changes in Accumulated Other Comprehensive Loss (AOCL) for the three months ended March 31, 2014 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 January 1, 2014 (a)	$	(10,672	)	$	(594	)	$	397	$	(10,869	)
	Other comprehensive income before reclassifications	—			—			62		62
	Amounts reclassified from AOCL (b)	—			8			—		8
	Net current period other comprehensive income	—			8			62		70
	Balance at March 31, 2014 (a)	$	(10,672	)	$	(586	)	$	459	$	(10,799	)
	(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 months ended March 31, 2014 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
		31-Mar-14
	Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		Interest Charges
	Unrealized Gain on Available-for-Sale Securities	—			Other Income & Expense
		12			Loss (Income) Before Income Taxes
	Income Taxes (a)	4			Income Taxes (a)
	Losses (Gains) from reclassifications for the period net of tax	$	8
	(a) Determined using a combined statutory tax rate of 41%.

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Accounting Policies [Abstract]	'	'
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales	$0.40	$0.40

STOCKBASED_COMPENSATION_PLANS_1

STOCK-BASED COMPENSATION PLANS (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Vesting period of shares	'3 years	'3 years
Shares Outstanding (in shares)	25,462	'
Fair Value Per Share (in dollars per share)	$50.18	'
Cost of Restricted Stock Awards	$0.10	$0.10
Unrecognized compensation cost of awards granted under the plan	0.8	'
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	'2 years 2 months 12 days	'
Shares [Roll Forward]	'	'
Nonvested Shares Outstanding, beginning balance (in shares)	15,068	'
Granted (in shares)	10,394	'
Nonvested Shares Outstanding, ending balance (in shares)	25,462	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, beginning balance (in dollars per share)	$50.73	'
Weighted Average Grant Date Fair Value, Granted (in dollars per share)	$49.38	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$50.18	'
Number of shares awarded during the period	0	12,901
Market value of shares awarded	'	0.6
Cash payments to SJI relating to stock awards	$0.40	$0.40
Grant Date January 2012 - TSR [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Shares Outstanding (in shares)	3,533	'
Fair Value Per Share (in dollars per share)	$51.23	'
Expected Volatility	22.50%	'
Risk-Free Interest Rate	0.43%	'
Shares [Roll Forward]	'	'
Nonvested Shares Outstanding, ending balance (in shares)	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	'
Grant Date January 2012 - EPS [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Shares Outstanding (in shares)	3,533	'
Fair Value Per Share (in dollars per share)	$56.93	'
Shares [Roll Forward]	'	'
Nonvested Shares Outstanding, ending balance (in shares)	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	'
Grant Date January 2013 - TSR [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Shares Outstanding (in shares)	4,001	'
Fair Value Per Share (in dollars per share)	$44.38	'
Expected Volatility	21.10%	'
Risk-Free Interest Rate	0.40%	'
Shares [Roll Forward]	'	'
Nonvested Shares Outstanding, ending balance (in shares)	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	'
Grant Date January 2013 - EPS [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Shares Outstanding (in shares)	4,001	'
Fair Value Per Share (in dollars per share)	$51.18	'
Shares [Roll Forward]	'	'
Nonvested Shares Outstanding, ending balance (in shares)	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	'
Grant Date January 2014, TSR [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Shares Outstanding (in shares)	5,197	'
Fair Value Per Share (in dollars per share)	$44.32	'
Expected Volatility	20.00%	'
Risk-Free Interest Rate	0.80%	'
Shares [Roll Forward]	'	'
Nonvested Shares Outstanding, ending balance (in shares)	5,197	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$44.32	'
Grant Date January 2014, EPS [Member]	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'
Shares Outstanding (in shares)	5,197	'
Fair Value Per Share (in dollars per share)	$54.44	'
Shares [Roll Forward]	'	'
Nonvested Shares Outstanding, ending balance (in shares)	5,197	'
Weighted Average Grant Date Fair Value [Roll Forward]	'	'
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$54.44	'
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) (Basic Gas Supply Service [Member], USD $)	1 Months Ended
In Millions, unless otherwise specified	Jan. 31, 2014
Basic Gas Supply Service [Member]	'
Schedule of Capitalization [Line Items]	'
BGSS refunds made to customers	$11.20

REGULATORY_ASSETS_AND_LIABILIT2

REGULATORY ASSETS AND LIABILITIES (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Regulatory Assets [Line Items]	'	'
Total regulatory assets	$309,290	$296,081
Environmental Restoration Costs: Expended - Net [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	26,590	29,945
Environmental Restoration Costs: Liability for Future Expenditures [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	119,604	119,492
Deferred Asset Retirement Obligation Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	31,347	31,142
Deferred Pension and Other Postretirement Benefit Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	59,284	59,284
Deferred Gas Costs - Net [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	34,008	0
Conservation Incentive Program Receivable [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	0	10,526
Societal Benefit Costs Receivable [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	5,528	10,408
Premium for Early Retirement of debt [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	0	955
Deferred Interest Rate Contracts [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	4,735	3,735
Energy Efficiency Tracker [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	7,470	10,420
Pipeline Supplier Service Charges [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	6,690	7,106
Pipeline Integrity Cost [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	2,962	2,902
AFUDC - Equity Related Deferrals [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	8,631	7,810
Other Regulatory Assets [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	$2,441	$2,356

REGULATORY_ASSETS_AND_LIABILIT3

REGULATORY ASSETS AND LIABILITIES REGULATORY ASSETS AND LIABILITIES 2 (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	$48,158	$60,949
Excess Plant Removal Costs [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	39,647	40,029
Deferred Revenues - Net [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	0	19,067
Conservation Incentive Program Payable [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	6,193	0
Other Regulatory Liabilities [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	$2,318	$1,853

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Related Party Transaction [Line Items]	'		'
Operating Revenues/Affiliates	$491		$709
Operations Expense/Affiliates	4,534		5,023
SJRG [Member]	'		'
Related Party Transaction [Line Items]	'		'
Operating Revenues/Affiliates	158		387
Costs of Sales/Affiliates (Excluding depreciation)	5,484		911
Energy-Related Derivative (Gains) / Losses	-1,030	[1]	1,457	[1]
Marina [Member]	'		'
Related Party Transaction [Line Items]	'		'
Operating Revenues/Affiliates	333		321
Other [Member]	'		'
Related Party Transaction [Line Items]	'		'
Operating Revenues/Affiliates	0		1
Operations Expense/Affiliates	-104		-128
SJI [Member]	'		'
Related Party Transaction [Line Items]	'		'
Operations Expense/Affiliates	4,030		2,922
SJIS [Member]	'		'
Related Party Transaction [Line Items]	'		'
Operations Expense/Affiliates	0		1,555
Millennium [Member]	'		'
Related Party Transaction [Line Items]	'		'
Operations Expense/Affiliates	$608		$674
[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 $)	Mar. 31, 2014	Dec. 31, 2013
Schedule of Financial Instruments [Line Items]	'	'
Restricted investments held in escrow	$100,000	$100,000
Margin accounts with selected counterparties to support risk management activities	800,000	500,000
Restricted investments, energy-related contracts	200,000	0
Long-term receivables, net of unamortized discount	'	15,000,000
Estimated fair value of long-term debt	531,300,000	486,500,000
Carrying amount of long-term debt	505,000,000	475,000,000
Financing Receivable [Member]	'	'
Schedule of Financial Instruments [Line Items]	'	'
Long-term receivables, net of unamortized discount	15,000,000	'
Imputed interest	$1,300,000	$1,300,000

LINES_OF_CREDIT_Details

LINES OF CREDIT (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Line of Credit Facility [Line Items]	'	'
Total Facility	$210,000,000	'
Usage	47,700,000	'
Available Liquidity	162,300,000	'
Average borrowings outstanding during the period	40,800,000	86,200,000
Maximum amounts outstanding during the period	66,000,000	103,000,000
Weighted average borrowing cost	0.25%	0.44%
Revolving Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Total Facility	200,000,000	'
Usage	47,700,000	'
Available Liquidity	152,300,000	'
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
	Jan. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
Pension Benefits [Member]	'	'	'
Net periodic benefit cost [Abstract]	'	'	'
Service cost	'	$966,000	$1,047,000
Interest cost	'	2,027,000	1,772,000
Expected return on plan assets	'	-2,455,000	-2,271,000
Amortizations [Abstract]	'	'	'
Prior service cost (credits)	'	33,000	48,000
Actuarial loss	'	1,072,000	1,649,000
Net Periodic Benefit Cost	'	1,643,000	2,245,000
Capitalized benefit costs	'	-854,000	-1,167,000
Total net periodic benefit expense	'	789,000	1,078,000
Contributions	9,100,000	0	'
Other Postretirement Benefits [Member]	'	'	'
Net periodic benefit cost [Abstract]	'	'	'
Service cost	'	172,000	238,000
Interest cost	'	510,000	535,000
Expected return on plan assets	'	-473,000	-449,000
Amortizations [Abstract]	'	'	'
Prior service cost (credits)	'	26,000	-54,000
Actuarial loss	'	167,000	351,000
Net Periodic Benefit Cost	'	402,000	621,000
Capitalized benefit costs	'	-209,000	-322,000
Total net periodic benefit expense	'	193,000	299,000
Defined benefit plan regulatory obligation to contribute to the plan during the period	'	3,600,000	'
Supplemental Employee Retirement Plans, Defined Benefit [Member]	'	'	'
Amortizations [Abstract]	'	'	'
Estimated future contributions	'	$1,200,000	'

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013
	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	4,100,000	'
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) (Fair Value, Measurements, Recurring [Member], USD $)	Mar. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Total [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	$8,808	[1]	$8,696	[1]
Derivatives - Energy Related Assets	2,190	[2]	1,500	[2]
Total Assets	10,998		10,196
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	466	[2]	759	[2]
Derivatives - Other	4,735	[3]	3,735	[3]
Total Liabilities	5,201		4,494
Level 1 [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	8,808	[1]	8,696	[1]
Derivatives - Energy Related Assets	2,190	[2]	1,409	[2]
Total Assets	10,998		10,105
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	466	[2]	155	[2]
Derivatives - Other	0	[3]	0	[3]
Total Liabilities	466		155
Level 2 [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	0	[1]	0	[1]
Derivatives - Energy Related Assets	0	[2]	91	[2]
Total Assets	0		91
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	0	[2]	604	[2]
Derivatives - Other	4,735	[3]	3,735	[3]
Total Liabilities	4,735		4,339
Level 3 [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	0	[1]	0	[1]
Derivatives - Energy Related Assets	0	[2]	0	[2]
Total Assets	0		0
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	0	[2]	0	[2]
Derivatives - Other	0	[3]	0	[3]
Total Liabilities	$0		$0
[1]	Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities 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.

DERIVATIVE_INSTRUMENTS_Details

DERIVATIVE INSTRUMENTS (Details) (USD $)	1 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2005	Mar. 31, 2014	Dec. 31, 2013
Derivative [Line Items]	'	'	'
Unrealized gains (losses) included in its BGSS related to open financial contracts	'	$1.70	($0.70)
Initial cost of Treasury Locks	1.4	'	'
Amortization period of Treasury Locks	'30 years	'	'
Unamortized balance of Treasury Locks	'	$1	$1
Natural Gas (in MMdts) [Member] | Derivative Transaction Type, Purchase [Member]	'	'	'
Derivative [Line Items]	'	'	'
Outstanding derivative contracts notional amount	'	11.8	'

DERIVATIVE_INSTRUMENTS_2_Detai

DERIVATIVE INSTRUMENTS 2 (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	$2,190	$1,500
Fair value Derivative Liabilities	5,201	4,494
Not Designated as Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	2,190	1,500
Fair value Derivative Liabilities	5,201	4,494
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-Current [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	2,121	1,222
Fair value Derivative Liabilities	280	711
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-NonCurrent [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	69	278
Fair value Derivative Liabilities	186	48
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	$4,735	$3,735

DERIVATIVE_INSTRUMENTS_DERIVAT

DERIVATIVE INSTRUMENTS DERIVATIVE INSTRUMENTS 3 (Details) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Commodity Contract [Member]	'		'
Offsetting Derivative Assets [Abstract]	'		'
Gross amounts of recognized assets/liabilities	$2,190		$1,500
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	2,190		1,500
Gross amounts not offset in the balance sheet, Financial Instruments	-466	[1]	-155	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		-498
Net amount	1,724		847
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-466		-759
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-466		-759
Gross amounts not offset in the balance sheet, Financial Instruments	466	[2]	155	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		0
Net amount	0		-604
Interest Rate Contract [Member]	'		'
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-4,735		-3,735
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-4,735		-3,735
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	($4,735)		($3,735)
[1]	The balances at March 31, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at March 31, 2013 and December 31, 2013 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
	Mar. 31, 2014		Mar. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'		'
Losses reclassified from Accumulated Other Comprehensive Loss into income	($12,000)	[1]	($12,000)	[1]
Net Realized gains (losses), derivative instruments, energy-related contracts	$2,400,000		($1,500,000)
[1]	Included in Interest Charges

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (Mortgages [Member], USD $)	Jan. 31, 2014
In Millions, unless otherwise specified
Mortgages [Member]	'
Debt Instrument [Line Items]	'
Debt issued	$30
Stated interest rate	4.23%

ACCUMULATED_OTHER_COMPREHENSIV2

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	($10,869)	[1]	'
Other comprehensive income before reclassifications	62		'
Amounts reclassified from AOCL	8	[2]	'
Other Comprehensive Gain (Loss) - Net of Tax	70	[1]	-267	[1]
Ending balance	-10,799	[1]	'
Combined statutory tax rate	41.00%		41.00%
Postretirement Liability Adjustment [Member]	'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	-10,672	[1]	'
Other comprehensive income before reclassifications	0		'
Amounts reclassified from AOCL	0	[2]	'
Other Comprehensive Gain (Loss) - Net of Tax	0		'
Ending balance	-10,672	[1]	'
Unrealized Gain (Loss) on Derivatives-Other [Member]	'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	-594	[1]	'
Other comprehensive income before reclassifications	0		'
Amounts reclassified from AOCL	8	[2]	'
Other Comprehensive Gain (Loss) - Net of Tax	8		'
Ending balance	-586	[1]	'
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]	'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	397	[1]	'
Other comprehensive income before reclassifications	62		'
Amounts reclassified from AOCL	0	[2]	'
Other Comprehensive Gain (Loss) - Net of Tax	62		'
Ending balance	$459	[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
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Interest Charges	$4,342		$2,961
Other Income and Expense	-1,086		-1,450
Income Before Income Taxes	-60,184		-56,284
Income Taxes	22,527		20,771
Net Income	-37,657		-35,513
Reclassification out of Accumulated Other Comprehensive Income [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Income Before Income Taxes	12		'
Income Taxes	4	[1]	'
Net Income	8		'
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		'
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		'
[1]	Determined using a combined statutory tax rate of 41% .

SUBSEQUENT_EVENT_Details

SUBSEQUENT EVENT (Details) (Subsequent Event [Member], USD $)	1 Months Ended
In Millions, unless otherwise specified	Apr. 30, 2014
Subsequent Event [Member]	'
Subsequent Event [Line Items]	'
Equity infusions from SJI	$12