SOUTH JERSEY GAS 10-Q 7 Nov 14 2014 Q3 Quarterly report Financial data

DOCUMENT_AND_ENTITY_INFORMATIO

DOCUMENT AND ENTITY INFORMATION Document	9 Months Ended
	Sep. 30, 2014	Nov. 03, 2014
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-14	'
Document Fiscal Year Focus	'2014	'
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, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Income Statement [Abstract]	'	'	'	'
Operating Revenues	$60,952	$59,674	$340,656	$300,308
Operating Expenses:	'	'	'	'
Cost of Sales (Excluding depreciation)	23,400	24,717	151,572	128,427
Operations	20,769	18,613	73,181	62,132
Maintenance	3,275	3,353	9,715	10,140
Depreciation	9,342	8,654	27,562	25,128
Energy and Other Taxes	798	1,052	2,813	5,332
Total Operating Expenses	57,584	56,389	264,843	231,159
Operating Income	3,368	3,285	75,813	69,149
Other Income and Expense	2,186	764	4,749	3,024
Interest Charges	-4,046	-2,629	-12,680	-8,379
Income Before Income Taxes	1,508	1,420	67,882	63,794
Income Taxes	-534	-471	-25,440	-23,511
Net Income	$974	$949	$42,442	$40,283

CONDENSED_STATEMENTS_OF_COMPRE

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Statement of Comprehensive Income [Abstract]	'		'		'		'
Net Income	$974		$949		$42,442		$40,283
Other Comprehensive (Loss) Gain - Net of Tax:	'		'		'		'
Unrealized (Loss) Gain on Available-for-Sale Securities	-613	[1]	221	[1]	-397	[1]	-76	[1]
Unrealized Gain on Derivatives - Other	6	[1]	7	[1]	21	[1]	21	[1]
Other Comprehensive (Loss) Gain - Net of Tax	-607	[1]	228	[1]	-376	[1]	-55	[1]
Comprehensive Income	$367		$1,177		$42,066		$40,228
[1]	Determined using a combined statutory tax rate of 41% .

CONDENSED_STATEMENTS_OF_COMPRE1

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Combined statutory tax rate	41.00%	41.00%	41.00%	41.00%

CONDENSED_STATEMENTS_OF_CASH_F

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Statement of Cash Flows [Abstract]	'	'
Net Cash Provided by Operating Activities	$55,242	$109,974
Cash Flows from Investing Activities:	'	'
Capital Expenditures	-139,393	-118,383
Net Purchase of Restricted Investments in Margin Accounts	-1,391	-809
Investment in Long-Term Receivables	-4,881	-5,012
Proceeds from Long-Term Receivables	5,075	5,376
Net Cash Used in Investing Activities	-140,590	-118,828
Cash Flows from Financing Activities:	'	'
Net (Repayments of)/Borrowings from Short-Term Credit Facilities	-6,200	7,900
Proceeds from Issuance of Long-Term Debt	89,000	0
Principal Repayments of Long-Term Debt	-21,000	-25,000
Payments for Issuance of Long-Term Debt	-627	-30
Additional Investment by Shareholder	25,000	25,000
Net Cash Provided by Financing Activities	86,173	7,870
Net Increase (Decrease) in Cash and Cash Equivalents	825	-984
Cash and Cash Equivalents at Beginning of Period	2,020	2,678
Cash and Cash Equivalents at End of Period	$2,845	$1,694

CONDENSED_BALANCE_SHEETS_UNAUD

CONDENSED BALANCE SHEETS (UNAUDITED) (USD $)	Sep. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment:	'		'
Utility Plant, at original cost	$1,955,876		$1,816,804
Accumulated Depreciation	-410,413		-392,029
Property, Plant and Equipment - Net	1,545,463		1,424,775
Investments:	'		'
Available-for-Sale Securities	8,990		8,696
Restricted Investments	2,071		680
Total Investments	11,061		9,376
Current Assets:	'		'
Cash and Cash Equivalents	2,845		2,020
Accounts Receivable	55,301		60,317
Accounts Receivable - Related Parties	810		968
Unbilled Revenues	7,820		41,510
Provision for Uncollectibles	-6,004		-4,553
Natural Gas in Storage, average cost	31,420		20,811
Materials and Supplies, average cost	1,195		1,798
Deferred Income Taxes - Net	30,434		23,309
Prepaid Taxes	20,838		7,683
Derivatives - Energy Related Assets	360		1,222
Other Prepayments and Current Assets	4,233		3,819
Total Current Assets	149,252		158,904
Regulatory and Other Noncurrent Assets:	'		'
Regulatory Assets	332,243		296,081
Unamortized Debt Issuance Costs	7,578		6,523
Long-Term Receivables	10,076		10,252
Derivatives - Energy Related Assets	47		278
Other	2,884		2,937
Total Regulatory and Other Noncurrent Assets	352,828		316,071
Total Assets	2,058,604		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	250,972		225,972
Accumulated Other Comprehensive Loss	-11,245	[1],[2]	-10,869	[1]
Retained Earnings	432,460		390,018
Total Common Equity	678,035		610,969
Long-Term Debt	533,000		454,000
Total Capitalization	1,211,035		1,064,969
Current Liabilities:	'		'
Notes Payable	59,300		65,500
Current Portion of Long-Term Debt	10,000		21,000
Accounts Payable - Commodity	11,479		24,232
Accounts Payable - Other	40,210		32,072
Accounts Payable - Related Parties	3,646		6,638
Derivatives - Energy Related Liabilities	3,069		711
Customer Deposits and Credit Balances	20,173		15,089
Environmental Remediation Costs	21,429		15,422
Taxes Accrued	1,650		1,767
Pension Benefits	1,241		1,241
Interest Accrued	5,060		6,039
Other Current Liabilities	4,145		5,629
Total Current Liabilities	181,402		195,340
Regulatory and Other Noncurrent Liabilities:	'		'
Regulatory Liabilities	46,104		60,949
Deferred Income Taxes - Net	414,681		380,975
Environmental Remediation Costs	98,435		104,070
Asset Retirement Obligations	41,842		41,178
Pension and Other Postretirement Benefits	50,926		48,197
Investment Tax Credits	201		360
Derivatives - Energy Related Liabilities	199		48
Derivatives - Other	5,778		3,735
Other	8,001		9,305
Total Regulatory and Other Noncurrent Liabilities	666,167		648,817
Commitments and Contingencies	'		'
Total Capitalization and Liabilities	$2,058,604		$1,909,126
[1]	Determined using a combined statutory tax rate of 41%.
[2]	Determined using a combined statutory tax rate of 41% .

CONDENSED_BALANCE_SHEETS_UNAUD1

CONDENSED BALANCE SHEETS (UNAUDITED) (Parenthetical) (USD $)	Sep. 30, 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	9 Months Ended
	Sep. 30, 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 or the Company), 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 Annual Report on Form 10-K for the year ended December 31, 2013 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 $0.2 million and $0.1 million for the three months ended September 30, 2014 and 2013, respectively and $0.8 million and $0.6 million for the nine months ended September 30, 2014 and 2013, respectively. In prior years, SJG 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.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606), This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or service to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.
	In August 2014, the FASB issued ASU 2014-15, "Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern," The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. Management does not expect this standard to have an impact on the Company's financial statements upon adoption.

STOCKBASED_COMPENSATION_PLANS

STOCK-BASED COMPENSATION PLANS	9 Months Ended
	Sep. 30, 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-Based Compensation Plan (Plan) of SJI. Restricted shares issued under the 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's 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 September 30, 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 September 30, 2014, there was $0.6 million of total unrecognized compensation cost related to nonvested share-based compensation awards granted under the Plan. That cost is expected to be recognized over a weighted average period of 1.9 years.
	The following table summarizes information regarding restricted stock award activity during the nine months ended September 30, 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, September 30, 2014	25,462		$	50.18
	Performance targets during the three-year vesting period were not attained for the January 2011 grant that vested at December 31, 2013. As a result, no shares were awarded in 2014. 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. SJG has a policy of making cash payments to SJI to satisfy its obligations under the Plan. Cash payments to SJI during each of the nine months ended September 30, 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	9 Months Ended
	Sep. 30, 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).
	Effective October 1, 2014, the BPU granted SJG a base rate increase of $20 million, which was predicated in part upon a 7.10% rate of return on rate base that included a 9.75% return on common equity. The $20 million base rate increase includes approximately $7.5 million associated with previously approved Accelerated Infrastructure Replacement Program (AIRP) investments that were rolled into rate base. SJG was also permitted to recover regulatory assets contained in its petition and reduce its composite depreciation rate from 2.4% to 2.1%.
	In May 2014, SJG filed its annual Energy Efficiency Tracker (EET) petition requesting a 0.19% increase in rates to recover the costs of, and the allowed return on, prior investments associated with energy efficiency programs. The petition is currently pending. Effective October 1, 2014, the BPU approved a revenue increase of $2.2 million associated with prior annual EET filings.
	Also effective October 1, 2014, the BPU approved a $6.4 million decrease in revenues associated with the Company’s Societal Benefits Program.
	In May 2014, SJG received BPU approval to continue the Conservation Incentive Program (CIP), with certain modifications.
	Also in May 2014, SJG filed its annual Basic Gas Supply Service (BGSS) and CIP petition, requesting a $4.9 million increase in annual revenues. The Petition proposes to recover over a two-year period higher than normal gas costs caused by colder than normal weather. The Petition also proposes to return to customers, through a reduction to the current CIP rate, excess margin recoveries caused by colder than normal weather. Provisional rates were approved by the BPU effective October 1, 2014.
	In September 2014, the BPU approved the statewide Universal Service Fund (USF) budget of $71.8 million for all the State’s gas utilities.  The Company’s portion of the total is approximately $7.9 million. Effective October 1, 2014, the BPU approved a $2.6 million increase to the Company’s USF recoveries.
	In August 2014, the BPU approved SJG’s Storm Hardening and Reliability Program (SHARP), authorizing SJG to invest $103.5 million over three years for system hardening on barrier islands.  SJG will earn on a return on these investments as they are made and will reflect the investments in base rates through annual rate adjustments.
	In January 2014, SJG credited the accounts of our periodic 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	9 Months Ended
	Sep. 30, 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):
		September 30, 2014		December 31, 2013
	Environmental Remediation Costs:
	Expended - Net	$	28,520	$	29,945
	Liability for Future Expenditures	119,864		119,492
	Deferred Asset Retirement Obligation Costs	31,598		31,142
	Deferred Pension and Other Postretirement Benefit Costs	59,284		59,284
	Deferred Gas Costs - Net	47,008		—
	Conservation Incentive Program Receivable	—		10,526
	Societal Benefit Costs Receivable	1,974		10,408
	Premium for Early Retirement of Debt	—		955
	Deferred Interest Rate Contracts (Note 11)	5,778		3,735
	Energy Efficiency Tracker	15,906		10,420
	Pipeline Supplier Service Charges	5,857		7,106
	Pipeline Integrity Cost	3,342		2,902
	AFUDC - Equity Related Deferrals	10,657		7,810
	Other Regulatory Assets	2,455		2,356
	Total Regulatory Assets	$	332,243	$	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 $47.0 million regulatory asset at September 30, 2014 was due to the actual cost of the commodity incurred during the first nine months of 2014 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 nine 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 and second quarters 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 half of 2014 resulting in increased recoveries of the deferred expense.
	Regulatory Liabilities consisted of the following items (in thousands):
		September 30, 2014		December 31, 2013
	Excess Plant Removal Costs	$	37,405	$	40,029
	Deferred Revenues-Net	—		19,067
	Conservation Incentive Program Payable	7,899		—
	Other Regulatory Liabilities	800		1,853
	Total Regulatory Liabilities	$	46,104	$	60,949
	EXCESS PLANT REMOVAL COSTS - Represents amounts accrued in excess of actual utility plant removal costs incurred to date. The decrease in the balance from year-end is due to an amortization as a credit to depreciation expense, as required as part of our September 2010 base rate increase, and an increase in retirement activity related to the AIRP projects.
	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.

RELATEDPARTY_TRANSACTIONS

RELATED-PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 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						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Operating Revenues/Affiliates:
	SJRG	$	169		$	344		$	552		$	1,194
	Marina	278			335			914			973
	Other	—			—			—			1
	Total Operating Revenue/Affiliates	$	447		$	679		$	1,466		$	2,168
	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,
		2014			2013			2014			2013
	Costs of Sales/Affiliates (Excluding depreciation):
	SJRG	$	1,686		$	5,436		$	8,612		$	11,105
	Energy-Related Derivative (Gains) / Losses *
	SJRG	$	(92	)	$	389		$	(1,612	)	$	568
	* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.
	Operations Expense/Affiliates
	SJI	$	2,901		$	2,737		$	10,079		$	8,613
	SJIS**	—			1,330			—			4,264
	Millennium	687			665			1,982			2,014
	Other	(111		)	(103		)	(327		)	(336		)
	Total Operations Expense/Affiliates	$	3,477		$	4,629		$	11,734		$	14,555
	** SJIS was dissolved effective January 1, 2014. All services previously provided by SJIS are currently being provided by SJI.

FINANCIAL_INSTRUMENTS

FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 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 September 30, 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 September 30, 2014 and December 31, 2013, the balance held with SJRG totaled $0.1 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 September 30, 2014, the balance held with this counterparty totaled $1.8 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 September 30, 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 $14.9 million and $15.0 million as of September 30, 2014 and December 31, 2013, 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 $1.2 million as of both September 30, 2014 and December 31, 2013.  The annualized amortization to interest is not material to SJG’s financial statements.  The carrying amounts of these receivables approximate their fair value at September 30, 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 September 30, 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 September 30, 2014 and December 31, 2013, were $572.2 million and $486.5 million, respectively.  The carrying amounts of SJG's long-term debt, including current maturities, as of September 30, 2014 and December 31, 2013 were $543.0 million and $475.0 million, respectively.

LINES_OF_CREDIT

LINES OF CREDIT	9 Months Ended
	Sep. 30, 2014
Line of Credit Facility [Abstract]	'
LINES OF CREDIT	'
	LINES OF CREDIT:
	Credit facilities and available liquidity as of September 30, 2014 were as follows (in thousands):
		Total Facility		Usage		Available Liquidity		Expiration Date
	Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	59,300	$	140,700	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Various
	Total	$	210,000	$	59,300	$	150,700
	The SJG revolving credit 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, 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 nine months ended September 30, 2014 and 2013 were $40.9 million and $90.5 million, respectively.  The maximum amount outstanding under these credit facilities during the nine months ended September 30, 2014 and 2013 were $70.1 million and $119.9 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 0.26% and 0.34% at September 30, 2014 and 2013, respectively.

PENSION_AND_OTHER_POSTRETIREME

PENSION AND OTHER POSTRETIREMENT BENEFITS	9 Months Ended
	Sep. 30, 2014
Compensation and Retirement Disclosure [Abstract]	'
PENSION AND OTHER POSTRETIREMENT BENEFITS	'
	PENSION AND OTHER POSTRETIREMENT BENEFITS:
	For the three and nine months ended  September 30, 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						Pension Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Service Cost	$	536		$	1,040		$	2,468		$	3,120
	Interest Cost	1,819			1,811			5,873			5,434
	Expected Return on Plan Assets	(2,233		)	(2,286		)	(7,143		)	(6,859		)
	Amortizations:
	Prior Service Cost	30			48			96			144
	Actuarial Loss	957			1,729			3,101			5,185
	Net Periodic Benefit Cost	1,109			2,342			4,395			7,024
	Capitalized Benefit Costs	(577		)	(1,218		)	(2,285		)	(3,653		)
	Total Net Periodic Benefit Expense	$	532		$	1,124		$	2,110		$	3,371
		Other Postretirement Benefits						Other Postretirement Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Service Cost	$	28		$	212		$	372		$	637
	Interest Cost	171			509			1,191			1,526
	Expected Return on Plan Assets	(202		)	(443		)	(1,148		)	(1,329		)
	Amortizations:
	Prior Service Cost (Credits)	11			(53		)	63			(159		)
	Actuarial Loss	73			324			407			972
	Net Periodic Benefit Cost	81			549			885			1,647
	Capitalized Benefit Costs	(42		)	(285		)	(460		)	(856		)
	Total Net Periodic Benefit Expense	$	39		$	264		$	425		$	791
	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 have been made or 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	9 Months Ended
	Sep. 30, 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 its 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 $3.9 million per month and is recovered on a current basis through the BGSS.
	PENDING LITIGATION - We are subject to claims arising in the ordinary course of business and other legal proceedings. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $0.5 million related to all claims in the aggregate as of both September 30, 2014 and December 31, 2013. 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, 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 was renegotiated this year and expires in August 2017.

FAIR_VALUE_OF_FINANCIAL_ASSETS

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	9 Months Ended
	Sep. 30, 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 September 30, 2014
		Total		Level 1		Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,990	$	8,990	$	—	$	—
	Derivatives – Energy Related Assets (B)	407		405		2		—
		$	9,397	$	9,395	$	2	$	—
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	3,268	$	1,287	$	1,981	$	—
	Derivatives – Other (C)	5,778		—		5,778		—
		$	9,046	$	1,287	$	7,759	$	—
	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.  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.
	(B)  Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
	(C)  Derivatives – Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model.  Market inputs can generally be verified and model selection does not involve significant management judgment.

DERIVATIVE_INSTRUMENTS

DERIVATIVE INSTRUMENTS	9 Months Ended
	Sep. 30, 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 September 30, 2014, SJG had outstanding derivative contracts intended to limit the exposure to market risk on 8.6 million decatherms (MMdts) of expected future purchases of natural gas and 0.3 MMdts of expected future sales of natural gas. In addition to these derivative contracts, SJG had basis and index related purchase and sales contracts totaling 3.9 MMdts. 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 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, 2014 and December 31, 2013, SJG had $2.5 million of unrealized losses 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 September 30, 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 September 30, 2014 and December 31, 2013, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	September 30, 2014						December 31, 2013
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	360		$	3,069		$	1,222		$	711
	Derivatives – Energy Related – Non-Current	47			199			278			48
	Interest rate contracts:
	Derivatives – Other	—			5,778			—			3,735
	Total derivatives not designated as hedging instruments under GAAP	407			9,046			1,500			4,494
	Total Derivatives	$	407		$	9,046		$	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 September 30, 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	$	407		$	—		$	407		$	(405	)	(A)	$	—		$	2
	Derivatives - Energy Related Liabilities	(3,268		)	—			(3,268		)	405			(B)	882			(1,981		)
	Derivatives - Other	(5,778		)	—			(5,778		)	—				—			(5,778		)
	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 September 30, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at September 30, 2014 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 and nine months ended September 30, 2014 and 2013 are as follows (in thousands):
		Three months ended						Nine months ended
		September 30,						September 30,
	Derivatives in Cash Flow Hedging Relationships	2014			2013			2014			2013
	Interest Rate Contracts:
	Losses reclassified from Accumulated Other Comprehensive Loss into income (a)	$	(12	)	$	(12	)	$	(36	)	$	(36	)
	(a) Included in Interest Charges
	Net realized loss of $1.2 million and $0.4 million associated with SJG's energy related financial commodity contracts for the three months ended September 30, 2014 and 2013, and gain of $2.4 million and loss of $0.6 million for the nine month ended September 30, 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, as applicable, and there is no impact to earnings.

LONGTERM_DEBT

LONG-TERM DEBT	9 Months Ended
	Sep. 30, 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.
	In June 2014, SJG entered into a $200.0 million multiple-draw term facility offered by a syndicate of banks which expires in June, 2017. SJG can draw under this facility through June, 2016 and this facility bears interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. As of September 30, 2014, SJG had borrowed an aggregate $59.0 million under this facility and the proceeds were used to pay down short-term debt.
	In July 2014, SJG retired $11.0 million aggregate principal amount of 4.52% MTN's at maturity. In September 2014, SJG retired $10.0 million aggregate principal amount of 5.115% MTN's at maturity.
	We retire debt when it is cost effective as permitted by the debt agreements.

ACCUMULATED_OTHER_COMPREHENSIV

ACCUMULATED OTHER COMPREHENSIVE LOSS	9 Months Ended
	Sep. 30, 2014
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, 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 July 1, 2014 (a)	$	(10,672	)	$	(579	)	$	613		$	(10,638	)
	Other comprehensive loss before reclassifications	—			—			(53		)	(53		)
	Amounts reclassified from AOCL (b)	—			6			(560		)	(554		)
	Net current period other comprehensive income (loss)	—			6			(613		)	(607		)
	Balance at September 30, 2014 (a)	$	(10,672	)	$	(573	)	$	—		$	(11,245	)
		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	—			—			163			163
	Amounts reclassified from AOCL (b)	—			21			(560		)	(539		)
	Net current period other comprehensive income (loss)	—			21			(397		)	(376		)
	Balance at September 30, 2014 (a)	$	(10,672	)	$	(573	)	$	—		$	(11,245	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
	The reclassifications out of AOCL during the three and nine months ended September 30, 2014 are 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-14			30-Sep-14
	Unrealized Gain on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		$	36		Interest Charges
	Unrealized Loss on Available-for-Sale Securities	(946		)	(946		)	Other Income & Expense
		(934		)	(910		)	Income Before Income Taxes
	Income Taxes (a)	(380		)	(371		)	Income Taxes (a)
	Losses from reclassifications for the period net of tax	$	(554	)	$	(539	)
	(a) Determined using a combined statutory tax rate of 41%.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
REVENUE AND THROUGHPUT BASED TAXES	'
	REVENUE AND THROUGHPUT - BASED TAXES - SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses.
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.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606), This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or service to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.
	In August 2014, the FASB issued ASU 2014-15, "Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern," The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. Management does not expect this standard to have an impact on the Company's financial statements upon adoption.
FAIR VALUE	'
	(A)  Available-for-Sale Securities include securities that are traded in active markets.  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.
	(B)  Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
	(C)  Derivatives – Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model.  Market inputs can generally be verified and model selection does not involve significant management judgment.

STOCKBASED_COMPENSATION_PLANS_

STOCK-BASED COMPENSATION PLANS (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 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 nine months ended September 30, 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, September 30, 2014	25,462		$	50.18

REGULATORY_ASSETS_AND_LIABILIT1

REGULATORY ASSETS AND LIABILITIES (Tables)	9 Months Ended
	Sep. 30, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Schedule of Regulatory Assets	'
	Regulatory Assets consisted of the following items (in thousands):
		September 30, 2014		December 31, 2013
	Environmental Remediation Costs:
	Expended - Net	$	28,520	$	29,945
	Liability for Future Expenditures	119,864		119,492
	Deferred Asset Retirement Obligation Costs	31,598		31,142
	Deferred Pension and Other Postretirement Benefit Costs	59,284		59,284
	Deferred Gas Costs - Net	47,008		—
	Conservation Incentive Program Receivable	—		10,526
	Societal Benefit Costs Receivable	1,974		10,408
	Premium for Early Retirement of Debt	—		955
	Deferred Interest Rate Contracts (Note 11)	5,778		3,735
	Energy Efficiency Tracker	15,906		10,420
	Pipeline Supplier Service Charges	5,857		7,106
	Pipeline Integrity Cost	3,342		2,902
	AFUDC - Equity Related Deferrals	10,657		7,810
	Other Regulatory Assets	2,455		2,356
	Total Regulatory Assets	$	332,243	$	296,081
Schedule of Regulatory Liabilities	'
	Regulatory Liabilities consisted of the following items (in thousands):
		September 30, 2014		December 31, 2013
	Excess Plant Removal Costs	$	37,405	$	40,029
	Deferred Revenues-Net	—		19,067
	Conservation Incentive Program Payable	7,899		—
	Other Regulatory Liabilities	800		1,853
	Total Regulatory Liabilities	$	46,104	$	60,949

RELATEDPARTY_TRANSACTIONS_Tabl

RELATED-PARTY TRANSACTIONS (Tables)	9 Months Ended
	Sep. 30, 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						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Operating Revenues/Affiliates:
	SJRG	$	169		$	344		$	552		$	1,194
	Marina	278			335			914			973
	Other	—			—			—			1
	Total Operating Revenue/Affiliates	$	447		$	679		$	1,466		$	2,168
	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,
		2014			2013			2014			2013
	Costs of Sales/Affiliates (Excluding depreciation):
	SJRG	$	1,686		$	5,436		$	8,612		$	11,105
	Energy-Related Derivative (Gains) / Losses *
	SJRG	$	(92	)	$	389		$	(1,612	)	$	568
	* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.
	Operations Expense/Affiliates
	SJI	$	2,901		$	2,737		$	10,079		$	8,613
	SJIS**	—			1,330			—			4,264
	Millennium	687			665			1,982			2,014
	Other	(111		)	(103		)	(327		)	(336		)
	Total Operations Expense/Affiliates	$	3,477		$	4,629		$	11,734		$	14,555
	** SJIS was dissolved effective January 1, 2014. All services previously provided by SJIS are currently being provided by SJI.

LINES_OF_CREDIT_Tables

LINES OF CREDIT (Tables)	9 Months Ended
	Sep. 30, 2014
Line of Credit Facility [Abstract]	'
Schedule of lines of credit	'
	Credit facilities and available liquidity as of September 30, 2014 were as follows (in thousands):
		Total Facility		Usage		Available Liquidity		Expiration Date
	Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	59,300	$	140,700	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Various
	Total	$	210,000	$	59,300	$	150,700

PENSION_AND_OTHER_POSTRETIREME1

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	9 Months Ended
	Sep. 30, 2014
Compensation and Retirement Disclosure [Abstract]	'
Schedule of defined benefit plans disclosures	'
	For the three and nine months ended  September 30, 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						Pension Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Service Cost	$	536		$	1,040		$	2,468		$	3,120
	Interest Cost	1,819			1,811			5,873			5,434
	Expected Return on Plan Assets	(2,233		)	(2,286		)	(7,143		)	(6,859		)
	Amortizations:
	Prior Service Cost	30			48			96			144
	Actuarial Loss	957			1,729			3,101			5,185
	Net Periodic Benefit Cost	1,109			2,342			4,395			7,024
	Capitalized Benefit Costs	(577		)	(1,218		)	(2,285		)	(3,653		)
	Total Net Periodic Benefit Expense	$	532		$	1,124		$	2,110		$	3,371
		Other Postretirement Benefits						Other Postretirement Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Service Cost	$	28		$	212		$	372		$	637
	Interest Cost	171			509			1,191			1,526
	Expected Return on Plan Assets	(202		)	(443		)	(1,148		)	(1,329		)
	Amortizations:
	Prior Service Cost (Credits)	11			(53		)	63			(159		)
	Actuarial Loss	73			324			407			972
	Net Periodic Benefit Cost	81			549			885			1,647
	Capitalized Benefit Costs	(42		)	(285		)	(460		)	(856		)
	Total Net Periodic Benefit Expense	$	39		$	264		$	425		$	791

FAIR_VALUE_OF_FINANCIAL_ASSETS1

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 2014
		Total		Level 1		Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,990	$	8,990	$	—	$	—
	Derivatives – Energy Related Assets (B)	407		405		2		—
		$	9,397	$	9,395	$	2	$	—
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	3,268	$	1,287	$	1,981	$	—
	Derivatives – Other (C)	5,778		—		5,778		—
		$	9,046	$	1,287	$	7,759	$	—
	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.  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.
	(B)  Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
	(C)  Derivatives – Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model.  Market inputs can generally be verified and model selection does not involve significant management judgment.

DERIVATIVE_INSTRUMENTS_Tables

DERIVATIVE INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 2014 and December 31, 2013, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	September 30, 2014						December 31, 2013
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	360		$	3,069		$	1,222		$	711
	Derivatives – Energy Related – Non-Current	47			199			278			48
	Interest rate contracts:
	Derivatives – Other	—			5,778			—			3,735
	Total derivatives not designated as hedging instruments under GAAP	407			9,046			1,500			4,494
	Total Derivatives	$	407		$	9,046		$	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 September 30, 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	$	407		$	—		$	407		$	(405	)	(A)	$	—		$	2
	Derivatives - Energy Related Liabilities	(3,268		)	—			(3,268		)	405			(B)	882			(1,981		)
	Derivatives - Other	(5,778		)	—			(5,778		)	—				—			(5,778		)
	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 September 30, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at September 30, 2014 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 and nine months ended September 30, 2014 and 2013 are as follows (in thousands):
		Three months ended						Nine months ended
		September 30,						September 30,
	Derivatives in Cash Flow Hedging Relationships	2014			2013			2014			2013
	Interest Rate Contracts:
	Losses reclassified from Accumulated Other Comprehensive Loss 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, 2014
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, 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 July 1, 2014 (a)	$	(10,672	)	$	(579	)	$	613		$	(10,638	)
	Other comprehensive loss before reclassifications	—			—			(53		)	(53		)
	Amounts reclassified from AOCL (b)	—			6			(560		)	(554		)
	Net current period other comprehensive income (loss)	—			6			(613		)	(607		)
	Balance at September 30, 2014 (a)	$	(10,672	)	$	(573	)	$	—		$	(11,245	)
		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	—			—			163			163
	Amounts reclassified from AOCL (b)	—			21			(560		)	(539		)
	Net current period other comprehensive income (loss)	—			21			(397		)	(376		)
	Balance at September 30, 2014 (a)	$	(10,672	)	$	(573	)	$	—		$	(11,245	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
Reclassifications out of AOCL	'
	The reclassifications out of AOCL during the three and nine months ended September 30, 2014 are 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-14			30-Sep-14
	Unrealized Gain on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		$	36		Interest Charges
	Unrealized Loss on Available-for-Sale Securities	(946		)	(946		)	Other Income & Expense
		(934		)	(910		)	Income Before Income Taxes
	Income Taxes (a)	(380		)	(371		)	Income Taxes (a)
	Losses from reclassifications for the period net of tax	$	(554	)	$	(539	)
	(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, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Accounting Policies [Abstract]	'	'	'	'
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales	$0.20	$0.10	$0.80	$0.60

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, 2014	Jun. 30, 2014	Mar. 31, 2014	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Sep. 30, 2014	Sep. 30, 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	'	'	'	'	'	25,462	'
Fair Value Per Share (in dollars per share)	$50.18	'	'	'	'	'	$50.18	'
Cost of Restricted Stock Awards	$0.10	$0.10	$0.10	$0.10	$0.10	$0.10	'	'
Unrecognized compensation cost of awards granted under the plan	0.6	'	'	'	'	'	0.6	'
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	'	'	'	'	'	'	'1 year 10 months 24 days	'
Shares [Roll Forward]	'	'	'	'	'	'	'	'
Nonvested Shares Outstanding, beginning balance (in shares)	'	'	15,068	'	'	'	15,068	'
Granted (in shares)	'	'	'	'	'	'	10,394	'
Nonvested Shares Outstanding, ending balance (in shares)	25,462	'	'	'	'	'	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	'	'	'	$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	'	'	'	'	'	$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	'	'	'	'	'	'	'	'
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	'	'	'	'	'	'	'	'
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	'	'	'	'	'	'	'	'
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	'	'	'	'	'	'	'	'
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	'
Grant Date January 2014, TSR	'	'	'	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'	'	'	'
Shares Outstanding (in shares)	5,197	'	'	'	'	'	5,197	'
Fair Value Per Share (in dollars per share)	$44.32	'	'	'	'	'	$44.32	'
Expected Volatility	'	'	'	'	'	'	20.00%	'
Risk-Free Interest Rate	'	'	'	'	'	'	0.80%	'
Shares [Roll Forward]	'	'	'	'	'	'	'	'
Nonvested Shares Outstanding, ending balance (in shares)	5,197	'	'	'	'	'	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	'	'	'	'	'	$44.32	'
Grant Date January 2014, EPS	'	'	'	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'	'	'	'
Shares Outstanding (in shares)	5,197	'	'	'	'	'	5,197	'
Fair Value Per Share (in dollars per share)	$54.44	'	'	'	'	'	$54.44	'
Shares [Roll Forward]	'	'	'	'	'	'	'	'
Nonvested Shares Outstanding, ending balance (in shares)	5,197	'	'	'	'	'	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	'	'	'	'	'	$54.44	'
Minimum	'	'	'	'	'	'	'	'
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	'	'	'	'	'	'	'	'
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	24 Months Ended	0 Months Ended					1 Months Ended
In Millions, unless otherwise specified	Aug. 31, 2014	Dec. 31, 2013	Oct. 01, 2014	Oct. 01, 2014	31-May-14	Oct. 01, 2014	Oct. 01, 2014	31-May-14	Jan. 31, 2014	Sep. 30, 2014	Oct. 01, 2014
			Subsequent Event	Accelerated Infrastructure Replacement Program	Energy Efficiency Tracker	Energy Efficiency Tracker	Societal Benefits Program	Basic Gas Supply Service	Basic Gas Supply Service	Universal Service Fund	Universal Service Fund
				Subsequent Event		Subsequent Event	Subsequent Event				Subsequent Event
Schedule of Capitalization [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Public utilities, approved base rate increase	'	'	$20	$7.50	'	'	'	'	'	'	'
Public utilities, rate of return on base rate	'	'	7.10%	'	'	'	'	'	'	'	'
Public utilities, return on common equity	'	'	9.75%	'	'	'	'	'	'	'	'
Costs requested for deferral, storm related	'	0	'	'	'	'	'	'	'	'	'
Public utilities, annual depreciation reduction attributable to petition	'	'	0	'	'	'	'	'	'	'	'
Increase (decrease) in amount of regulatory costs approved	'	'	'	'	'	2.2	-6.4	4.9	'	7.9	'
Amount of regulatory costs approved, percent change in recoveries	'	'	'	'	0.19%	'	'	'	'	'	'
Proposed recovery period of expenditures	'	'	'	'	'	'	'	'2 years	'	'	'
Amount of regulatory costs approved, statewide	'	'	'	'	'	'	'	'	'	71.8	'
Amount of regulatory costs not yet approved, annual revenue impact	'	'	'	'	'	'	'	'	'	'	2.6
BGSS refunds made to customers	'	'	'	'	'	'	'	'	11.2	'	'
Investment requested to be recovered through SHARP	$103.50	'	'	'	'	'	'	'	'	'	'
Investment requested to be recovered through SHARP, term	'3 years	'	'	'	'	'	'	'	'	'	'

REGULATORY_ASSETS_AND_LIABILIT2

REGULATORY ASSETS AND LIABILITIES (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Regulatory Assets [Line Items]	'	'
Total regulatory assets	$332,243	$296,081
Environmental Remediation Costs: Expended - Net	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	28,520	29,945
Environmental Remediation Costs: Liability for Future Expenditures	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	119,864	119,492
Deferred Asset Retirement Obligation Costs	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	31,598	31,142
Deferred Pension and Other Postretirement Benefit Costs	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	59,284	59,284
Deferred Gas Costs - Net	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	47,008	0
Conservation Incentive Program Receivable	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	0	10,526
Societal Benefit Costs Receivable	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	1,974	10,408
Premium for Early Retirement of debt	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	0	955
Deferred Interest Rate Contracts	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	5,778	3,735
Energy Efficiency Tracker	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	15,906	10,420
Pipeline Supplier Service Charges	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	5,857	7,106
Pipeline Integrity Cost	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	3,342	2,902
AFUDC - Equity Related Deferrals	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	10,657	7,810
Other Regulatory Assets	'	'
Regulatory Assets [Line Items]	'	'
Total regulatory assets	$2,455	$2,356

REGULATORY_ASSETS_AND_LIABILIT3

REGULATORY ASSETS AND LIABILITIES REGULATORY ASSETS AND LIABILITIES 2 (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	$46,104	$60,949
Excess Plant Removal Costs	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	37,405	40,029
Deferred Revenues - Net	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	0	19,067
Conservation Incentive Program Payable	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	7,899	0
Other Regulatory Liabilities	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	$800	$1,853

RELATEDPARTY_TRANSACTIONS_Deta

RELATED-PARTY TRANSACTIONS (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Related Party Transaction [Line Items]	'		'		'		'
Operating Revenues/Affiliates	$447		$679		$1,466		$2,168
Operations Expense/Affiliates	3,477		4,629		11,734		14,555
SJRG	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operating Revenues/Affiliates	169		344		552		1,194
Costs of Sales/Affiliates (Excluding depreciation)	1,686		5,436		8,612		11,105
Energy-Related Derivative (Gains) / Losses	-92	[1]	389	[1]	-1,612	[1]	568	[1]
Marina	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operating Revenues/Affiliates	278		335		914		973
Other	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operating Revenues/Affiliates	0		0		0		1
Operations Expense/Affiliates	-111		-103		-327		-336
SJI	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operations Expense/Affiliates	2,901		2,737		10,079		8,613
SJIS	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operations Expense/Affiliates	0	[2]	1,330	[2]	0	[2]	4,264	[2]
Millennium	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Operations Expense/Affiliates	$687		$665		$1,982		$2,014
[1]	Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.
[2]	SJIS was dissolved effective January 1, 2014. All services previously provided by SJIS are currently being provided by SJI.

FINANCIAL_INSTRUMENTS_Details

FINANCIAL INSTRUMENTS (Details) (USD $)	Sep. 30, 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	100,000	500,000
Restricted investments, energy-related contracts	1,800,000	0
Estimated fair value of long-term debt	572,200,000	486,500,000
Carrying amount of long-term debt	543,000,000	475,000,000
Financing Receivable	'	'
Schedule of Financial Instruments [Line Items]	'	'
Long-term receivables, net of unamortized discount	14,900,000	15,000,000
Imputed interest	$1,200,000	$1,200,000

LINES_OF_CREDIT_Details

LINES OF CREDIT (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Line of Credit Facility [Line Items]	'	'
Total Facility	$210,000,000	'
Usage	59,300,000	'
Available Liquidity	150,700,000	'
Average borrowings outstanding during the period	40,900,000	90,500,000
Maximum amounts outstanding during the period	70,100,000	119,900,000
Weighted average borrowing cost	0.26%	0.34%
Revolving Credit Facility	'	'
Line of Credit Facility [Line Items]	'	'
Total Facility	200,000,000	'
Usage	59,300,000	'
Available Liquidity	140,700,000	'
Expiration Date	'May 2018	'
Uncommitted Bank Lines	'	'
Line of Credit Facility [Line Items]	'	'
Total Facility	10,000,000	'
Usage	0	'
Available Liquidity	10,000,000	'
Expiration Date	'Various	'
South Jersey Gas Commercial Paper Program	'	'
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	'	'
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	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Pension Benefits	'	'	'	'	'
Net periodic benefit cost [Abstract]	'	'	'	'	'
Service cost	'	$536,000	$1,040,000	$2,468,000	$3,120,000
Interest cost	'	1,819,000	1,811,000	5,873,000	5,434,000
Expected return on plan assets	'	-2,233,000	-2,286,000	-7,143,000	-6,859,000
Amortizations [Abstract]	'	'	'	'	'
Prior service cost (credits)	'	30,000	48,000	96,000	144,000
Actuarial loss	'	957,000	1,729,000	3,101,000	5,185,000
Net Periodic Benefit Cost	'	1,109,000	2,342,000	4,395,000	7,024,000
Capitalized benefit costs	'	-577,000	-1,218,000	-2,285,000	-3,653,000
Total net periodic benefit expense	'	532,000	1,124,000	2,110,000	3,371,000
Contributions	9,100,000	'	'	0	'
Other Postretirement Benefits	'	'	'	'	'
Net periodic benefit cost [Abstract]	'	'	'	'	'
Service cost	'	28,000	212,000	372,000	637,000
Interest cost	'	171,000	509,000	1,191,000	1,526,000
Expected return on plan assets	'	-202,000	-443,000	-1,148,000	-1,329,000
Amortizations [Abstract]	'	'	'	'	'
Prior service cost (credits)	'	11,000	-53,000	63,000	-159,000
Actuarial loss	'	73,000	324,000	407,000	972,000
Net Periodic Benefit Cost	'	81,000	549,000	885,000	1,647,000
Capitalized benefit costs	'	-42,000	-285,000	-460,000	-856,000
Total net periodic benefit expense	'	39,000	264,000	425,000	791,000
Defined benefit plan regulatory obligation to contribute to the plan during the period	'	'	'	3,600,000	'
Supplemental Employee Retirement Plans, Defined Benefit	'	'	'	'	'
Amortizations [Abstract]	'	'	'	'	'
Estimated future contributions	'	'	'	$1,200,000	'

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
	unions	sites
	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	3,900,000	'
Estimated litigation liability	500,000	500,000
Percentage of personnel represented in collective bargaining agreements	60.00%	'
Number of unions	2	'
Standby Letter of Credit	'	'
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, USD $)	Sep. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Total [Member]	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	$8,990	[1]	$8,696	[1]
Derivatives - Energy Related Assets	407	[2]	1,500	[2]
Total Assets	9,397		10,196
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	3,268	[2]	759	[2]
Derivatives - Other	5,778	[3]	3,735	[3]
Total Liabilities	9,046		4,494
Level 1	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	8,990	[1]	8,696	[1]
Derivatives - Energy Related Assets	405	[2]	1,409	[2]
Total Assets	9,395		10,105
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	1,287	[2]	155	[2]
Derivatives - Other	0	[3]	0	[3]
Total Liabilities	1,287		155
Level 2	'		'
Assets [Abstract]	'		'
Available-for-sale Securities	0	[1]	0	[1]
Derivatives - Energy Related Assets	2	[2]	91	[2]
Total Assets	2		91
Liabilities [Abstract]	'		'
Derivatives - Energy Related Liabilities	1,981	[2]	604	[2]
Derivatives - Other	5,778	[3]	3,735	[3]
Total Liabilities	7,759		4,339
Level 3	'		'
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. 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.
[2]	Derivatives b Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
[3]	Derivatives b Other, include interest rate swaps that are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

DERIVATIVE_INSTRUMENTS_Details

DERIVATIVE INSTRUMENTS (Details) (USD $)	1 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2005	Sep. 30, 2014	Dec. 31, 2013
Derivative [Line Items]	'	'	'
Unrealized gains (losses) included in its BGSS related to open financial contracts	'	($2.50)	$0.70
Initial cost of Treasury Locks	1.4	'	'
Amortization period of Treasury Locks (in years)	'30 years	'	'
Unamortized balance of Treasury Locks	'	$1	$1
Basis and Index Related Purchase and Sales Contracts	'	'	'
Derivative [Line Items]	'	'	'
Outstanding derivative contracts notional amount (MMdts)	'	3.9	'
Natural Gas (in MMdts) | Derivative Transaction Type, Purchase	'	'	'
Derivative [Line Items]	'	'	'
Outstanding derivative contracts notional amount (MMdts)	'	8.6	'
Natural Gas (in MMdts) | Derivative Transaction Type, Sale	'	'	'
Derivative [Line Items]	'	'	'
Outstanding derivative contracts notional amount (MMdts)	'	0.3	'

DERIVATIVE_INSTRUMENTS_2_Detai

DERIVATIVE INSTRUMENTS 2 (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	$407	$1,500
Fair value Derivative Liabilities	9,046	4,494
Not Designated as Hedging Instrument	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	407	1,500
Fair value Derivative Liabilities	9,046	4,494
Commodity Contract | Not Designated as Hedging Instrument | Derivatives-Energy Related-Current	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	360	1,222
Fair value Derivative Liabilities	3,069	711
Commodity Contract | Not Designated as Hedging Instrument | Derivatives-Energy Related-NonCurrent	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	47	278
Fair value Derivative Liabilities	199	48
Interest Rate Contract | Not Designated as Hedging Instrument | Derivatives-Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$5,778	$3,735

DERIVATIVE_INSTRUMENTS_DERIVAT

DERIVATIVE INSTRUMENTS DERIVATIVE INSTRUMENTS 3 (Details) (USD $)	Sep. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Commodity Contract	'		'
Offsetting Derivative Assets [Abstract]	'		'
Gross amounts of recognized assets/liabilities	$407		$1,500
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	407		1,500
Gross amounts not offset in the balance sheet, Financial Instruments	-405	[1]	-155	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		-498
Net amount	2		847
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-3,268		-759
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-3,268		-759
Gross amounts not offset in the balance sheet, Financial Instruments	405	[2]	155	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	882		0
Net amount	-1,981		-604
Interest Rate Contract	'		'
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-5,778		-3,735
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-5,778		-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	($5,778)		($3,735)
[1]	The balances at September 30, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at September 30, 2014 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				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'		'		'		'
Losses reclassified from Accumulated Other Comprehensive Loss into income	($12,000)	[1]	($12,000)	[1]	($36,000)	[1]	($36,000)	[1]
Net Realized gains (losses), derivative instruments, energy-related contracts	($1,200,000)		($400,000)		$2,400,000		($600,000)
[1]	Included in Interest Charges

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014	Jul. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Jan. 31, 2014
			Medium-term notes	Medium-term notes	Line of Credit	Line of Credit	Mortgages
							Series Due January 2030, 4.23%
Debt Instrument [Line Items]	'	'	'	'	'	'	'
Debt issued	'	'	'	'	'	'	$30,000,000
Stated interest rate	'	'	5.12%	4.52%	'	'	4.23%
Borrowing capacity	210,000,000	'	'	'	'	200,000,000	'
Carrying amount of long-term debt	543,000,000	475,000,000	'	'	59,000,000	'	'
Debt retired	'	'	$10,000,000	$11,000,000	'	'	'

ACCUMULATED_OTHER_COMPREHENSIV2

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	($10,638)	[1]	'		($10,869)	[2]	'
Other comprehensive income before reclassifications	-53		'		163		'
Amounts reclassified from AOCL	-554	[3]	'		-539	[3]	'
Other Comprehensive (Loss) Gain - Net of Tax	-607	[1]	228	[1]	-376	[1]	-55	[1]
Ending balance	-11,245	[1],[2]	'		-11,245	[1],[2]	'
Combined statutory tax rate	41.00%		41.00%		41.00%		41.00%
Postretirement Liability Adjustment	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	-10,672	[1]	'		-10,672	[2]	'
Other comprehensive income before reclassifications	0		'		0		'
Amounts reclassified from AOCL	0	[3]	'		0	[3]	'
Other Comprehensive (Loss) Gain - Net of Tax	0		'		0		'
Ending balance	-10,672	[1],[2]	'		-10,672	[1],[2]	'
Unrealized Gain (Loss) on Derivatives-Other	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	-579	[1]	'		-594	[2]	'
Other comprehensive income before reclassifications	0		'		0		'
Amounts reclassified from AOCL	6	[3]	'		21	[3]	'
Other Comprehensive (Loss) Gain - Net of Tax	6		'		21		'
Ending balance	-573	[1],[2]	'		-573	[1],[2]	'
Unrealized Gain (Loss) on Available-for-Sale Securities	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	613	[1]	'		397	[2]	'
Other comprehensive income before reclassifications	-53		'		163		'
Amounts reclassified from AOCL	-560	[3]	'		-560	[3]	'
Other Comprehensive (Loss) Gain - Net of Tax	-613		'		-397		'
Ending balance	$0	[1],[2]	'		$0	[1],[2]	'
[1]	Determined using a combined statutory tax rate of 41% .
[2]	Determined using a combined statutory tax rate of 41%.
[3]	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, 2014		Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Interest Charges	$4,046		$2,629	$12,680		$8,379
Other Income and Expense	-2,186		-764	-4,749		-3,024
Income Before Income Taxes	-1,508		-1,420	-67,882		-63,794
Income Taxes	534		471	25,440		23,511
Net Income	-974		-949	-42,442		-40,283
Reclassification out of Accumulated Other Comprehensive Income	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Income Before Income Taxes	-934		'	-910		'
Income Taxes	-380	[1]	'	-371	[1]	'
Net Income	-554		'	-539		'
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Gain (Loss) on Derivatives-Other	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Interest Charges	12		'	36		'
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Gain (Loss) on Available-for-Sale Securities	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Other Income and Expense	($946)		'	($946)		'
[1]	Determined using a combined statutory tax rate of 41%.