South Jersey Industries (SJIIU) 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. 01, 2014
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'SOUTH JERSEY INDUSTRIES INC	'
Entity Central Index Key	'0000091928	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Document Type	'10-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	'	33,646,410

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Operating Revenues:	'	'	'	'
Utility	$60,756	$59,302	$339,988	$298,993
Nonutility	61,671	69,506	265,911	208,037
Total Operating Revenues	122,427	128,808	605,899	507,030
Cost of Sales - (Excluding depreciation)	'	'	'	'
- Utility	23,205	24,345	150,905	127,111
- Nonutility	52,868	64,815	232,253	202,176
Operations	29,939	27,216	99,941	87,862
Maintenance	3,275	3,354	9,715	10,141
Depreciation	16,057	12,826	46,543	36,605
Energy and Other Taxes	1,196	1,458	4,390	6,955
Total Operating Expenses	126,540	134,014	543,747	470,850
Operating Income (Loss)	-4,113	-5,206	62,152	36,180
Other Income and Expense	3,419	2,200	9,972	8,734
Interest Charges	-6,768	-4,393	-20,698	-12,521
Income (Loss) Before Income Taxes	-7,462	-7,399	51,426	32,393
Income Taxes	8,325	5,533	5,966	9,393
Equity in (Loss) Earnings of Affiliated Companies	-5,139	645	-3,756	1,246
Income (Loss) from Continuing Operations	-4,276	-1,221	53,636	43,032
Loss from Discontinued Operations - (Net of tax benefit)	-120	-200	-513	-699
Net Income (Loss)	($4,396)	($1,421)	$53,123	$42,333
Basic Earnings Per Common Share:	'	'	'	'
Continuing Operations (in dollars per share)	($0.13)	($0.04)	$1.62	$1.35
Discontinued Operations (in dollars per share)	$0	$0	($0.01)	($0.02)
Basic Earnings Per Common Share (in dollars per share)	($0.13)	($0.04)	$1.61	$1.33
Average Shares of Common Stock Outstanding - Basic (in shares)	33,166	31,984	32,966	31,898
Diluted Earnings Per Common Share:	'	'	'	'
Continuing Operations (in dollars per share)	($0.13)	($0.04)	$1.62	$1.35
Discontinued Operations (in dollars per share)	$0	$0	($0.01)	($0.02)
Diluted Earnings Per Common Share (in dollars per share)	($0.13)	($0.04)	$1.61	$1.33
Average Shares of Common Stock Outstanding - Diluted (in shares)	33,166	31,984	33,041	31,959
Dividends Declared per Common Share (in dollars per share)	$0.47	$0.44	$1.41	$1.33

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED 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 (Loss)	($4,396)		($1,421)		$53,123		$42,333
Other Comprehensive (Loss) Income, Net of Tax:	'		'		'		'
Unrealized (Loss) Gain on Available-for-Sale Securities	-613	[1]	221	[1]	-397	[1]	-76	[1]
Unrealized Gain on Derivatives - Other	66	[1]	66	[1]	198	[1]	198	[1]
Other Comprehensive Income (Loss) of Affiliated Companies	63	[1]	-25	[1]	-37	[1]	5,011	[1]
Other Comprehensive (Loss) Income - Net of Tax	-484	[1]	262	[1]	-236	[1]	5,133	[1]
Comprehensive Income (Loss)	($4,880)		($1,159)		$52,887		$47,466
[1]	Determined using a combined statutory tax rate of 41%.

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED 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_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED 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	$109,042	$123,425
Cash Flows from Investing Activities:	'	'
Capital Expenditures	-203,918	-192,497
Proceeds from Sale of Property, Plant and Equipment	0	6
Net Purchase of Restricted Investments in Margin Account	-4,815	-5,802
Purchase of Restricted Investments with Escrowed Loan Proceeds	0	-47
Investment in Long-Term Receivables	-4,881	-5,012
Proceeds from Long-Term Receivables	5,075	5,376
Purchase of Company Owned Life Insurance	-1,172	-5,072
Investment in Affiliate	0	-2,973
Advances on Notes Receivable - Affiliate	-3,472	-11,849
Repayment of Notes Receivable - Affiliate	4,761	94,946
Net Cash Used in Investing Activities	-208,422	-122,924
Cash Flows from Financing Activities:	'	'
Net (Repayments of) Borrowings from Short-Term Credit Facilities	-204,500	38,600
Proceeds from Issuance of Long-Term Debt	329,000	0
Principal Repayments of Long-Term Debt	-21,000	-25,000
Payments for Issuance of Long-Term Debt	-2,159	-30
Dividends on Common Stock	-31,121	-28,246
Proceeds from Sale of Common Stock	29,125	13,931
Net Cash Provided by (Used in) Financing Activities	99,345	-745
Net Decrease in Cash and Cash Equivalents	-35	-244
Cash and Cash Equivalents at Beginning of Period	3,818	4,638
Cash and Cash Equivalents at End of Period	$3,783	$4,394

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED 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
Nonutility Property and Equipment, at cost	536,081		486,332
Accumulated Depreciation	-70,619		-52,009
Property, Plant and Equipment - Net	2,010,925		1,859,098
Investments:	'		'
Available-for-Sale Securities	9,013		8,716
Restricted	47,929		43,115
Investment in Affiliates	72,866		78,273
Total Investments	129,808		130,104
Current Assets:	'		'
Cash and Cash Equivalents	3,783		3,818
Accounts Receivable	202,987		253,566
Unbilled Revenues	17,128		47,594
Provision for Uncollectibles	-7,278		-5,854
Notes Receivable - Affiliate	9,213		8,908
Natural Gas in Storage, average cost	60,609		57,786
Materials and Supplies, average cost	2,200		2,798
Deferred Income Taxes - Net	46,365		30,609
Prepaid Taxes	21,884		9,431
Derivatives - Energy Related Assets	47,032		56,327
Other Prepayments and Current Assets	21,758		17,915
Total Current Assets	425,681		482,898
Regulatory and Other Noncurrent Assets:	'		'
Regulatory Assets	332,243		296,081
Derivatives - Energy Related Assets	13,384		26,451
Unamortized Debt Issuance Costs	10,114		7,803
Notes Receivable-Affiliate	38,527		39,907
Contract Receivables	14,174		14,595
Notes Receivable	7,882		7,882
Other	60,945		60,036
Total Regulatory and Other Noncurrent Assets	477,269		452,755
Total Assets	3,043,683		2,924,855
Equity:	'		'
Common Stock	41,553		40,894
Premium on Common Stock	431,244		401,011
Treasury Stock (at par)	-163		-186
Accumulated Other Comprehensive Loss	-20,996	[1]	-20,760	[1]
Retained Earnings	412,336		406,041
Total Equity	863,974		827,000
Long-Term Debt	935,400		680,400
Total Capitalization	1,799,374		1,507,400
Current Liabilities:	'		'
Notes Payable	149,400		353,900
Current Portion of Long-Term Debt	74,000		21,000
Accounts Payable	211,602		259,757
Customer Deposits and Credit Balances	20,646		15,546
Environmental Remediation Costs	23,276		16,695
Taxes Accrued	2,400		3,234
Derivatives - Energy Related Liabilities	92,518		77,993
Dividends Payable	15,707		0
Interest Accrued	6,744		6,363
Pension Benefits	1,241		1,275
Other Current Liabilities	6,594		9,210
Total Current Liabilities	604,128		764,973
Deferred Credits and Other Noncurrent Liabilities:	'		'
Deferred Income Taxes - Net	329,934		319,368
Investment Tax Credits	201		360
Pension and Other Postretirement Benefits	61,000		57,370
Environmental Remediation Costs	100,612		106,734
Asset Retirement Obligations	42,364		41,687
Derivatives - Energy Related Liabilities	16,783		22,131
Derivatives - Other	8,821		6,676
Regulatory Liabilities	46,104		60,949
Finance Obligation	19,916		20,656
Other	14,446		16,551
Total Deferred Credits and Other Noncurrent Liabilities	640,181		652,482
Commitments and Contingencies	'		'
Total Capitalization and Liabilities	$3,043,683		$2,924,855
[1]	Determined using a combined statutory tax rate of 41%.

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:
	GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy related products and services primarily through the following subsidiaries:
	▪	South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey.
	▪	South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers.
	▪	South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets on a wholesale basis in the mid-Atlantic, Appalachian and southern states.
	▪	South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.
	▪	Marina Energy, LLC (Marina) develops and operates on-site energy-related projects.
	▪	South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.
	BASIS OF PRESENTATION — The condensed consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management’s opinion, the condensed consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI’s financial position, operating results and cash flows at the dates and for the periods presented. SJI’s businesses are 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 (SEC), the accompanying unaudited condensed consolidated financial statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These financial statements should be read in conjunction with SJI’s 2013 Annual Report on Form 10-K for a more complete discussion of the Company’s 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 in Note 8.
	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 utility revenue 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.
	IMPAIRMENT OF LONG-LIVED ASSETS - SJI reviews the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the nine months ended September 30, 2014 and 2013, no impairments were identified.
	GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. No impairment was recorded during the nine months ended September 30, 2014 or 2013. As of September 30, 2014 and December 31, 2013, $9.0 million and $8.9 million, respectively, related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with Nonutility Property and Equipment and Other Noncurrent Assets on the condensed consolidated balance sheets.
	TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of September 30, 2014 and December 31, 2013, SJI held 130,007 and 148,890 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI.
	INCOME TAXES — Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 740 - “Income Taxes”.  A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow through method, which may result in variations in the customary relationship between income taxes and pre-tax income for interim periods.
	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 consolidated financial statements.
	In July 2013, the FASB issued Accounting Standards 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 April 2014, the FASB issued ASU 2014-08 "Presentation of Financial Statements and Property, Plant and Equipment: Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity." This ASU changes the presentation of discontinued operations on the statements of income and other requirements for reporting discontinued operations. Under the new standard, only those disposals of components of an entity that represent a strategic shift that has (or will have) a major effect on an entity's operations and financial results should be reported as a discontinued operation. This ASU also requires additional disclosures about discontinued operations and disposal of an individually significant component of an entity that does not qualify for discontinued operations. The new accounting guidance is effective for interim and annual periods beginning after December 15, 2014, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have 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 services 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. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption.

STOCKBASED_COMPENSATION_PLAN

STOCK-BASED COMPENSATION PLAN	9 Months Ended
	Sep. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
STOCK-BASED COMPENSATION PLAN	'
	STOCK-BASED COMPENSATION PLAN:
	Under the Amended and Restated 1997 Stock-Based Compensation Plan, no more than 2,000,000 shares in the aggregate may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. The plan will terminate on January 26, 2015, unless terminated earlier by the Board of Directors. No options were granted or outstanding during the nine months ended September 30, 2014 and 2013.  No stock appreciation rights have been issued under the plan. During the nine months ended September 30, 2014 and 2013, SJI granted 68,453 and 56,464 restricted shares, respectively, to Officers and other key employees.  These restricted shares vest over a three-year period and are subject to SJI achieving certain market and earnings-based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 150% of the original share units granted.
	Grants containing market-based performance targets 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.
	During the nine months ended September 30, 2014 and 2013, SJI granted 11,610 and 12,285 restricted shares, respectively, to Directors.  Shares issued to Directors vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest.
	See Note 2 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013 for the related accounting policy.
	The following table summarizes the nonvested restricted stock awards outstanding at September 30, 2014 and the assumptions used to estimate the fair value of the awards:
		Grant Date		Shares Outstanding			Fair Value Per Share				Expected Volatility			Risk-Free Interest Rate
	Officers & Key Employees -	Jan. 2012 - TSR		18,268			$	51.23			22.5	%		0.43	%
		Jan. 2012 - EPS		18,268			$	56.93			N/A			N/A
		Jan. 2013 - TSR		24,797			$	44.38			21.1	%		0.4	%
		Jan. 2013 - EPS		24,797			$	51.18			N/A			N/A
		Jan. 2014 - TSR		31,267			$	44.32			20	%		0.8	%
		Jan. 2014 - EPS		31,267			$	54.44			N/A			N/A
	Directors -	Jan. 2014		11,610			$	54.51			N/A			N/A
	Expected volatility is based on the actual volatility of SJI’s share price over the preceding three-year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three-year term of the Officers’ and other key employees’ restricted shares. As notional dividend equivalents are credited to the holders during the three-year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant.
	The following table summarizes the total stock-based compensation cost for the three and nine months ended September 30, 2014 and 2013 (in thousands):
		Three Months Ended							Nine Months Ended
		September 30,							September 30,
		2014			2013				2014				2013
	Officers & Key Employees	$	584		$	565			$	1,751			$	1,696
	Directors	159			191				475				574
	Total Cost	743			756				2,226				2,270
	Capitalized	(70		)	(59		)		(210		)		(178		)
	Net Expense	$	673		$	697			$	2,016			$	2,092
	As of September 30, 2014, there was $3.5 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the Plan. That cost is expected to be recognized over a weighted average period of 1.8 years.
	The following table summarizes information regarding restricted stock award activity during the nine months ended September 30, 2014, excluding accrued dividend equivalents:
		Officers &Other Key Employees			Directors			Weighted
								Average
								Fair Value
	Nonvested Shares Outstanding, January 1, 2014	94,192			19,617			$	50.73
	Granted	68,453			11,610			$	50.12
	Cancelled/Forfeited	(13,981	)		—			$	49.85
	Vested	—			(19,617	)		$	52.19
	Nonvested Shares Outstanding, September 30, 2014	148,664			11,610			$	50.33
	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 66,077 shares to its Officers and other key employees, which had vested at December 31, 2012, at a market value of $3.3 million. Also, during the nine months ended September 30, 2014 and 2013, SJI granted 11,610 and 12,285 shares to its Directors at a market value of $0.6 million for each period. The Company has a policy of issuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of these plans. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash.  At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods.  These deferred shares are included in Treasury Stock on the condensed consolidated balance sheets.

DISCONTINUED_OPERATIONS_AND_AF

DISCONTINUED OPERATIONS AND AFFILIATIONS	9 Months Ended
	Sep. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
DISCONTINUED OPERATIONS AND AFFILATIONS	'
	DISCONTINUED OPERATIONS AND AFFILATIONS:
	Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (EMI), an SJI subsidiary, which previously operated a fuel oil business. Morie is the former sand mining and processing subsidiary of EMI. EMI sold the common stock of Morie in 1996.
	SJI conducts tests annually to estimate the environmental remediation costs for these properties.
	Summarized operating results of the discontinued operations for the three and nine months ended September 30, were (in thousands, except per share amounts):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Loss Before Income Taxes:
	Sand Mining	$	(79	)	$	(287	)	$	(562	)	$	(379	)
	Fuel Oil	(105		)	(22		)	(227		)	(697		)
	Income Tax Benefits	64			109			276			377
	Loss from Discontinued Operations — Net	$	(120	)	$	(200	)	$	(513	)	$	(699	)
	Earnings (Loss) Per Common Share from
	Discontinued Operations — Net:
	Basic and Diluted	—			—			(0.01		)	(0.02		)
	AFFILIATIONS — The following affiliated entities are accounted for under the equity method:
	Energenic – US, LLC (Energenic) - Marina and a joint venture partner formed Energenic, in which Marina has a 50% equity interest. Energenic develops and operates on-site, self-contained, energy-related projects.
	In April 2012, Energenic acquired The Energy Network, LLC, a holding company for the Hartford Steam Company, TEN Companies and CNE Power I, LLC. In conjunction with this acquisition, Marina provided $35.4 million of advances to Energenic, which was repaid by Energenic during the second quarter of 2013 as permanent financing was obtained.
	Potato Creek, LLC (Potato Creek) - SJI and a joint venture partner formed Potato Creek, in which SJI has a 30% equity interest.  Potato Creek owns and manages the oil, gas and mineral rights of certain real estate in Pennsylvania.
	LVE Energy Partners, LLC (LVE) - In March 2013, substantially all of the assets of Marina's joint venture, LVE, an entity in which Marina had a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.9 million in 2013. LVE was dissolved prior to December 31, 2013. See Note 11.
	During the first nine months of 2014, the Company received net repayments from unconsolidated affiliates of $1.3 million. During the first nine months of 2013, the Company made investments in, and provided net advances to, unconsolidated affiliates of $12.9 million, excluding the cash proceeds related to the sale of LVE and the repayment of the advances to Energenic as discussed above. As of September 30, 2014 and December 31, 2013, the outstanding balance on these Notes Receivable – Affiliate was $47.7 million and $48.8 million, respectively. These notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025.
	SJI holds significant variable interests in these entities but is not the primary beneficiary. Consequently, these entities are accounted for under the equity method because SJI does not have both a) the power to direct the activities of the entity that most significantly impact the entity’s economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the entity or the right to receive benefits from the entity that could potentially be significant to the entity. As of September 30, 2014, the Company had a net asset of approximately $72.0 million included in Investment in Affiliates and Other Noncurrent Liabilities on the condensed consolidated balance sheets related to equity method investees, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of September 30, 2014 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $120.6 million plus the guarantees discussed in Note 11.

COMMON_STOCK

COMMON STOCK	9 Months Ended
	Sep. 30, 2014
Common Stock [Abstract]	'
COMMON STOCK	'
	COMMON STOCK:
	The following shares were issued and outstanding:
		2014
	Beginning Balance, January 1	32,715,042
	New Issues During the Period:
	Dividend Reinvestment Plan	516,050
	Stock-Based Compensation Plan	11,610
	Ending Balance, September 30	33,242,702
	The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $30.2 million was recorded in Premium on Common Stock.
	EARNINGS PER COMMON SHARE (EPS) — Basic EPS is based on the weighted-average number of common shares outstanding.  The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 75,296 and 61,315 for the nine months ended September 30, 2014 and 2013, respectively. For the three months ended September 30, 2014 and 2013, incremental shares of 74,332 and 67,196 were not included in the denominator for the diluted EPS calculation because they would have an antidilutive effect on EPS. These shares relate to SJI's restricted stock as discussed in Note 2.
	DIVIDEND REINVESTMENT PLAN (DRP) —The Company offers a DRP which allows participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases. Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $29.1 million and $13.9 million of equity capital through the DRP during the nine months ended September 30, 2014 and 2013, respectively.

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 certain Marina and SJG loan agreements, unused proceeds are required to be escrowed pending approval of construction expenditures. As of September 30, 2014 and December 31, 2013, the escrowed proceeds, including interest earned, totaled $1.4 million and $1.3 million, respectively.
	The Company maintains margin accounts with selected counterparties to support its risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy-related contracts with the respective counterparties decrease. As of September 30, 2014 and December 31, 2013, the balances in these accounts totaled $46.5 million and $41.8 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at September 30, 2014 and December 31, 2013, which would be included in Level 1 of the fair value hierarchy (See Note 13 - 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 Contract Receivables on the condensed consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.2 million and $1.3 million as of September 30, 2014 and December 31, 2013, respectively.  The annualized amortization to interest is not material to the Company’s condensed consolidated 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 13 - Fair Value of Financial Assets and Financial Liabilities).
	CREDIT RISK - As of September 30, 2014, approximately $19.3 million, or 31.9%, of the current and noncurrent Derivatives – Energy Related Assets are transacted with two, investment-grade rated counterparties.
	FINANCE OBLIGATION - During 2010, ACB Energy Partners LLC (ACB), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, completed construction of a combined heat and power generating facility to serve, under an energy services agreement, a thermal plant owned by Marina. Construction period financing was provided by Marina. As substantially all of the costs of constructing the facility were funded by the financing provided by Marina, Marina was considered the owner of the facility for accounting purposes during the construction period. When an entity is considered the accounting owner during the construction period, a sale of the asset effectively occurs when construction of the asset is completed. However, due to its continuing involvement in the facility through its equity interest in Energenic, Marina continues to be considered the owner of the facility for accounting purposes under ASC Topic 360 Property, Plant and Equipment. As a result, the transaction is being accounted for as a financing arrangement under ASC Topic 840 Leases and, therefore, the Company has included costs to construct the facility within Nonutility Property, Plant and Equipment on the condensed consolidated balance sheets of $23.7 million as of both September 30, 2014 and December 31, 2013. In addition, the Company included repayments from ACB to Marina on the construction loan within the Finance Obligation on the condensed consolidated balance sheets. Marina does not have a fixed payment obligation to ACB; as a result, the Finance Obligation is classified as a noncurrent liability on the condensed consolidated balance sheets. The costs to construct the facility and the repayments of the construction loan are amortized over the term of the energy services agreement related to the project. The impact on the condensed consolidated statements of income is not significant. As a result, the Company recorded $19.9 million and $20.7 million, net of amortization, within Finance Obligation on the condensed consolidated balance sheets at September 30, 2014 and December 31, 2013, respectively.
	FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJI's financial instruments approximate their fair values at 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 SJI at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy, see Note 13 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJI's long-term debt, including current maturities, as of September 30, 2014 and December 31, 2013, were $1,041.9 million and $713.2 million, respectively.  The carrying amounts of SJI's long-term debt, including current maturities, as of September 30, 2014 and December 31, 2013, were $1,009.4 million and $701.4 million, respectively.

SEGMENTS_OF_BUSINESS

SEGMENTS OF BUSINESS	9 Months Ended
	Sep. 30, 2014
Segment Reporting [Abstract]	'
SEGMENTS OF BUSINESS	'
	SEGMENTS OF BUSINESS:
	SJI operates in several different reportable operating segments. These segments are as follows:
	•	Gas utility operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers.
	•	Wholesale energy operations include the activities of SJRG and SJEX.
	•	SJE is involved in both retail gas and retail electric activities.
	◦	Retail gas and other operations include natural gas acquisition and transportation service business lines.
	◦	Retail electric operations consist of electricity acquisition and transportation to commercial and industrial customers.
	•	On-site energy production consists of Marina's thermal energy facility and other energy-related projects.
	•	Appliance service operations includes SJESP’s servicing of appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.
	In the first quarter of 2014, SJI began grouping its non-utility operations into two areas: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes on-site energy production and appliance service operations. Due to this grouping, some of the Company's prior period numbers were recast to conform with the current period presentation. However, no changes were made to the specific reportable operating segments. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices.
	Information about SJI’s operations in different reportable operating segments is presented below (in thousands):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014				2013
	Operating Revenues:
	Gas Utility Operations	$	60,952		$	59,674		$	340,656			$	300,308
	Energy Group:
	Wholesale Energy Operations	(3,538		)	128			28,898				(4,354		)
	Retail Gas and Other Operations	18,900			19,588			95,281				78,286
	Retail Electric Operations	29,961			36,063			98,233				98,211
	Subtotal Energy Group	45,323			55,779			222,412				172,143
	Energy Services:
	On-Site Energy Production	16,453			14,254			42,196				33,313
	Appliance Service Operations	2,319			2,974			7,610				9,415
	Subtotal Energy Services	18,772			17,228			49,806				42,728
	Corporate & Services	7,001			7,126			21,324				22,968
	Subtotal	132,048			139,807			634,198				538,147
	Intersegment Sales	(9,621		)	(10,999		)	(28,299		)		(31,117		)
	Total Operating Revenues	$	122,427		$	128,808		$	605,899			$	507,030
		Three Months Ended							Nine Months Ended
		September 30,							September 30,
		2014			2013				2014				2013
	Operating Income (Loss):
	Gas Utility Operations	$	3,368		$	3,285			$	75,813			$	69,149
	Energy Group:
	Wholesale Energy Operations	(10,314		)	(8,969		)		(20,437		)		(33,326		)
	Retail Gas and Other Operations	(390		)	(125		)		1,387				(257		)
	Retail Electric Operations	373			(146		)		(521		)		(19		)
	Subtotal Energy Group	(10,331		)	(9,240		)		(19,571		)		(33,602		)
	Energy Services:
	On-Site Energy Production	2,171			111				4,547				(794		)
	Appliance Service Operations	60			532				322				1,317
	Subtotal Energy Services	2,231			643				4,869				523
	Corporate and Services	619			106				1,041				110
	Total Operating (Loss) Income	$	(4,113	)	$	(5,206	)		$	62,152			$	36,180
	Depreciation and Amortization:
	Gas Utility Operations	$	12,942		$	12,476			$	38,375			$	36,429
	Energy Group:
	Wholesale Energy Operations	37			51				123				157
	Retail Gas and Other Operations	19			21				61				64
	Subtotal Energy Group	56			72				184				221
	Energy Services:
	On-Site Energy Production	6,540			4,008				18,480				10,978
	Appliance Service Operations	68			47				202				193
	Subtotal Energy Services	6,608			4,055				18,682				11,171
	Corporate and Services	(41		)	207				413				653
	Total Depreciation and Amortization	$	19,565		$	16,810			$	57,654			$	48,474
	Interest Charges:
	Gas Utility Operations	$	4,046		$	2,629			$	12,680			$	8,379
	Energy Group:
	Wholesale Energy Operations	74			148				190				233
	Retail Gas and Other Operations	43			73				237				216
	Subtotal Energy Group	117			221				427				449
Energy Services:
On-Site Energy Production	1,835			1,274				6,110				2,984
Corporate and Services	2,376			1,488				6,016				4,208
Subtotal	8,374			5,612				25,233				16,020
Intersegment Borrowings	(1,606		)	(1,219		)		(4,535		)		(3,499		)
Total Interest Charges	$	6,768		$	4,393			$	20,698			$	12,521
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2014			2013			2014				2013
Income Taxes:
Gas Utility Operations	$	534		$	471		25,440				23,511
Energy Group:
Wholesale Energy Operations	(3,896		)	(3,616		)	(7,077		)		(13,307		)
Retail Gas and Other Operations	(121		)	(72		)	895				148
Retail Electric Operations	152			(59		)	(213		)		(8		)
Subtotal Energy Group	(3,865		)	(3,747		)	(6,395		)		(13,167		)
Energy Services:
On-Site Energy Production	(5,092		)	(2,547		)	(25,521		)		(20,577		)
Appliance Service Operations	39			232			227				574
Subtotal Energy Services	(5,053		)	(2,315		)	(25,294		)		(20,003		)
Corporate and Services	59			58			283				266
Total Income Taxes	$	(8,325	)	$	(5,533	)	$	(5,966	)		$	(9,393	)
Property Additions:
Gas Utility Operations	$	56,414		$	46,426		$	148,012			$	128,232
Energy Group:
Wholesale Energy Operations	—			8			10				42
Retail Gas and Other Operations	563			7			960				44
Subtotal Energy Group	563			15			970				86
Energy Services:
On-Site Energy Production	22,194			55,737			47,769				73,263
Appliance Service Operations	8			—			14				—
Subtotal Energy Services	22,202			55,737			47,783				73,263
Corporate and Services	1,144			706			2,725				2,570
Total Property Additions	$	80,323		$	102,884		$	199,490			$	204,151
	September 30, 2014			December 31, 2013
Identifiable Assets:
Gas Utility Operations	$	2,058,604		$	1,909,126
Energy Group:
Wholesale Energy Operations	271,304			331,182
Retail Gas and Other Operations	30,956			50,384
Retail Electric Operations	24,325			25,496
Subtotal Energy Group	326,585			407,062
Energy Services:
On-Site Energy Production	614,985			576,315
Appliance Service Operations	2,852			1,812
Subtotal Energy Services	617,837			578,127
Discontinued Operations	1,766			1,068
Corporate and Services	421,466			406,245
Intersegment Assets	(382,575		)	(376,773		)
Total Identifiable Assets	$	3,043,683		$	2,924,855

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 $20.0 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 $20.0 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 SJG'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.  SJG's portion of the total is approximately $7.9 million. Effective October 1, 2014, the BPU approved a $2.6 million increase to SJG'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 its 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 10 to the Consolidated Financial Statements in Item 8 of SJI's Annual Report on Form 10-K as of December 31, 2013.

REGULATORY_ASSETS_REGULATORY_L

REGULATORY ASSETS & REGULATORY LIABILITIES	9 Months Ended
	Sep. 30, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]	'
REGULATORY ASSETS & REGULATORY LIABILITIES	'
	REGULATORY ASSETS & REGULATORY LIABILITIES:
	There have been no significant changes to the nature of the Company’s regulatory assets and liabilities since December 31, 2013 which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on 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	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 program. 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 SJG's 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.

PENSION_AND_OTHER_POSTRETIREME

PENSION AND OTHER POSTRETIREMENT BENEFITS	9 Months Ended
	Sep. 30, 2014
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans 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
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Service Cost	$	813		$	1,356		$	3,383		$	4,066
	Interest Cost	2,661			2,360			8,051			7,079
	Expected Return on Plan Assets	(3,262		)	(2,979		)	(9,792		)	(8,936		)
	Amortizations:
	Prior Service Cost	45			63			131			188
	Actuarial Loss	1,398			2,251			4,250			6,754
	Net Periodic Benefit Cost	1,655			3,051			6,023			9,151
	Capitalized Benefit Costs	(577		)	(1,218		)	(2,285		)	(3,653		)
	Total Net Periodic Benefit Expense	$	1,078		$	1,833		$	3,738		$	5,498
		Other Postretirement Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Service Cost	$	168		$	285		$	668		$	855
	Interest Cost	659			682			2,139			2,047
	Expected Return on Plan Assets	(688		)	(595		)	(2,062		)	(1,784		)
	Amortizations:
	Prior Service Cost (Credits)	38			(71		)	114			(213		)
	Actuarial Loss	245			435			731			1,304
	Net Periodic Benefit Cost	422			736			1,590			2,209
	Capitalized Benefit Costs	(42		)	(286		)	(460		)	(856		)
	Total Net Periodic Benefit Expense	$	380		$	450		$	1,130		$	1,353
	Capitalized benefit costs reflected in the table above relate to SJG’s construction program.
	SJI contributed $12.7 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 $1.3 million in 2014. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred. See Note 12 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013, for additional information related to SJI’s pension and other postretirement benefits.

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):
	Company	Total Facility		Usage		Available Liquidity		Expiration Date
	SJG:
	Commercial Paper Program/Revolving Credit Facility	$	200,000	$	59,300	$	140,700	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Various
	Total SJG	210,000		59,300		150,700
	SJI:
	Revolving Credit Facility	400,000		103,800		296,200		February 2018 (A)
	Total SJI	400,000		103,800		296,200
	Total	$	610,000	$	163,100	$	446,900
	(A) Includes letters of credit outstanding in the amount of $13.7 million.
	The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 0.83% and 0.98% at September 30, 2014 and 2013, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the nine months ended September 30, 2014 and 2013 were $291.6 million and $297.2 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the nine months ended September 30, 2014 and 2013 were $390.7 million and $389.4 million, respectively.
	The SJI and SJG facilities are provided by a syndicate of banks and contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements) to not more than 0.65 to 1, measured at the end of each fiscal quarter. SJI and SJG were in compliance with this covenant as of 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 its $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.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	COMMITMENTS AND CONTINGENCIES:
	GUARANTEES — The Company has recorded a liability of $0.7 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of September 30, 2014 for the fair value of the following guarantees:
	In April 2007, SJI guaranteed certain obligations of LVE Energy Partners, LLC (LVE), an unconsolidated joint venture in which Marina had a 50% equity interest.  LVE entered into a 25-year contract with a resort developer to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.  LVE began construction of the facility in 2007 and expected to provide full energy service in 2010 when the resort was originally scheduled to be completed.  LVE suspended construction of the district energy system and central energy center in January 2009 after the resort developer’s announcement that it was delaying the completion of construction of the resort.
	In March 2013, the resort developer purchased substantially all of the assets of LVE. As a result, the guarantees provided by SJI of certain performance obligations of LVE under the operating agreements between LVE and the resort developer were canceled.
	In 2013, the Company received 1) $57.9 million of repayments of advances to LVE; and 2) a $7.9 million note receivable from a third party, which is recorded in the condensed consolidated balance sheets as of September 30, 2014. As of December 31, 2013, LVE was dissolved and the Company incurred a $0.8 million charge to write-off its remaining interest in 2013.
	SJI has guaranteed certain obligations of WC Landfill Energy, LLC (WCLE) and BC Landfill Energy, LLC (BCLE), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. WCLE and BCLE have entered into agreements through 2018 and 2027, respectively, with the respective county governments to lease and operate facilities that will produce electricity from landfill methane gas.  Although unlikely, the maximum amount that SJI could be obligated for, in the event that WCLE and BCLE do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due, is approximately $4.2 million each year.  SJI and its partner in these joint ventures have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.  SJI holds variable interests in WCLE and BCLE but is not the primary beneficiary.
	In December 2013, SJI entered into agreements to guarantee certain obligations of WCLE, SC Landfill Energy, LLC, SX Landfill Energy, LLC, FC Landfill Energy, LLC, and AC Landfill Energy, LLC (collectively, the "Landfills"), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. The Landfills have entered into long-term debt agreements which run through 2020. Although unlikely, SJI could be liable through the guarantees for 50% of the outstanding debt along with any interest related to the debt in the event the Landfills do not meet minimum specified levels of operating performance and no mitigating action is taken, or the Landfils are unable to meet certain financial obligations as they become due. As of September 30, 2014, 50% of the currently outstanding debt is $9.0 million. As a result, the Company has recorded a liability of $0.4 million for the fair value of the guarantees, which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of September 30, 2014.
	During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex.  Marina and its joint venture partner have provided a $5.0 million letter of credit to support certain operating performance obligations of Energenic under the operating agreements. Marina and its partner in this joint venture have entered into a reimbursement agreement that secures reimbursement for Marina of a proportionate share of any payments made by Marina to or on behalf of Energenic.
	In June 2014 the parent company of the hotel, casino and entertainment complex announced that it was filing petitions in U. S. Bankruptcy Court to address liquidity issues and facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014 and an agreement of sale was subsequently approved by the court. Although there can be no assurances, the sale is scheduled to close during the fourth quarter of 2014. Energenic subsidiaries continue to provide limited energy services to the complex during the shutdown period. The buyer, which owns several other casino resorts, has indicated that it plans to reopen the complex.
	As of September 30, 2014, the Company, through its investment in Energenic, had a net asset of approximately $23.3 million included in Investment in Affiliates on the condensed consolidated balance sheets related to this project. In addition, the Company had approximately $13.7 million included in Notes Receivable - Affiliate on the condensed consolidated balance sheets, due from an Energenic subsidiary, which is secured by certain assets of the central energy center. This note is also subject to a reimbursement agreement that secures reimbursement for the Company, from its joint venture partner, of a proportionate share of any amounts that are not repaid.
	As a result of the bankruptcy filing and the pending sale of the complex, management has evaluated the investment in this project and the related note receivable and concluded that, based on the current situation, the fair value of this investment continues to be in excess of the respective carrying values as of September 30, 2014. Management will continue to monitor the situation surrounding the complex, including the status of the energy services agreement between the Energenic subsidiary and the complex, and will evaluate the value of the investment as future events occur.
	In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, in which Marina has a 50% equity interest, entered into a 30 year contract with a public university to build, own and operate a combined heating, cooling and power system for its main campus in New Jersey. The system commenced commercial operations in September 2013. SJI has guaranteed certain obligations of UMM under the operating and lease agreements between UMM and the university, for the terms of the agreements, commencing with the first year of operations. SJI has guaranteed up to $2.2 million for the first year. This amount is adjusted each year based upon the Consumer Price Index. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.
	As of September 30, 2014, SJI had issued $5.8 million of guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.
	COLLECTIVE BARGAINING AGREEMENTS — Unionized personnel represent approximately 45.0% of our workforce at September 30, 2014. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76.  SJG and SJESP employees represented by the IBEW operate under a collective bargaining agreement that runs through February 2017. The remaining unionized employees are represented by the IAM and operate under a collective bargaining agreement that expires in August 2017.
	STANDBY LETTERS OF CREDIT — As of September 30, 2014, SJI provided $13.7 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.
	PENDING LITIGATION — The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.0 million 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.
	ENVIRONMENTAL REMEDIATION COSTS — SJI incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. SJI and some of its nonutility subsidiaries also recorded costs for environmental cleanup of sites where SJF previously operated a fuel oil business and Morie maintained equipment, fueling stations and storage. There have been no changes to the status of the Company’s environmental remediation efforts since December 31, 2013 as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013.

DERIVATIVE_INSTRUMENTS

DERIVATIVE INSTRUMENTS	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
DERIVATIVE INSTRUMENTS	'
	DERIVATIVE INSTRUMENTS:
	Certain SJI subsidiaries are involved in buying, selling, transporting and storing natural gas and buying and selling retail electricity for their own accounts as well as managing these activities for third parties. These subsidiaries are subject to market risk on expected future purchases and sales due to commodity price fluctuations. The Company uses a variety of derivative instruments to limit this exposure to market risk in accordance with strict corporate guidelines.  These derivative instruments include forward contracts, swap agreements, options contracts and futures contracts. As of September 30, 2014, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 42.3 MMdts (1 MMdts =ne million decatherms) of expected future purchases of natural gas, 35.6 MMdts of expected future sales of natural gas, 0.9 MMmwh (1 MMmwh =ne million megawatt hours) of expected future purchases of electricity and 1.0 MMmwh of expected future sales of electricity. In addition to these derivative contracts, the Company has basis and index related purchase and sales contracts totaling 164.1 MMdts.  These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives — Energy Related Assets or Derivatives — Energy Related Liabilities on the condensed consolidated balance sheets. The net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility.
	The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, some of which have been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the condensed consolidated balance sheets. Beginning in July 2012, hedge accounting was discontinued for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously included in Accumulated Other Comprehensive Loss (AOCL) on the consolidated balance sheets, will be reclassified into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026.
	There have been no significant changes to the Company’s active interest rate swaps since December 31, 2013 which are described in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013.
	The fair values of all derivative instruments, as reflected in the condensed consolidated 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	$	47,032		$	92,518		$	56,327		$	77,993
	Derivatives – Energy Related – Non-Current	13,384			16,783			26,451			22,131
	Interest rate contracts:
	Derivatives - Other	—			8,821			—			6,676
	Total derivatives not designated as hedging instruments under GAAP	60,416			118,122			82,778			106,800
	Total Derivatives	$	60,416		$	118,122		$	82,778		$	106,800
	The Company enters into derivative contracts with counterparties, some of which are subject to master netting arrangements, which allow net settlements under certain conditions. The Company presents derivatives at gross fair values on the condensed consolidated balance sheets. As of September 30, 2014 and December 31, 2013, information related to these offsetting arrangements were 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	$	60,416		$	—		$	60,416		$	(27,540	)	(A)	$	—		$	32,876
	Derivatives - Energy Related Liabilities	$	(109,301	)	$	—		$	(109,301	)	$	27,540		(B)	$	33,973		$	(47,788	)
	Derivatives - Other	$	(8,821	)	$	—		$	(8,821	)	$	—			$	—		$	(8,821	)
	As of December 31, 2013
	Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet			Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
											Financial Instruments				Cash Collateral Posted
	Derivatives - Energy Related Assets	$	82,778		$	—		$	82,778		$	(28,082	)	(A)	$	(498	)	$	54,198
	Derivatives - Energy Related Liabilities	$	(100,124	)	$	—		$	(100,124	)	$	28,082		(B)	$	29,639		$	(42,403	)
	Derivatives - Other	$	(6,676	)	$	—		$	(6,676	)	$	—			$	—		$	(6,676	)
	(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 consolidated 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 under GAAP	2014			2013			2014			2013
	Interest Rate Contracts:
	Losses recognized in AOCL on effective portion	$	—		$	—		$	—		$	—
	Losses reclassified from AOCL into income (a)	$	(112	)	$	(112	)	$	(336	)	$	(336	)
	Gains (losses) recognized in income on ineffective portion (a)	$	—		$	—		$	—		$	—
	(a) Included in Interest Charges
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
	Derivatives Not Designated as Hedging Instruments under GAAP	2014			2013			2014			2013
	Losses on energy related commodity contracts (a)	$	(1,633	)	$	(537	)	$	(30,429	)	$	(24,308	)
	Gains (losses) on interest rate contracts (b)	202			390			(103		)	2,165
	Total	$	(1,431	)	$	(147	)	$	(30,532	)	$	(22,143	)
	(a)  Included in Operating Revenues - Non Utility
	(b)  Included in Interest Charges
	Net realized losses associated with SJG's energy-related financial commodity contracts of $1.2 million and $0.4 million for the three months ended September 30, 2014 and 2013, respectively, and a gain of $2.4 million and a loss of $0.6 million for the nine months 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.
	Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on September 30, 2014, is $33.1 million.  If the credit-risk-related contingent features underlying these agreements were triggered on September 30, 2014, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $24.5 million after offsetting asset positions with the same counterparties under master netting arrangements.

FAIR_VALUE_OF_FINANCIAL_ASSETS

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	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)	$	9,013			$	9,013			$	—	$	—
	Derivatives – Energy Related Assets (B)	60,416				3,350				18,068		38,998
		$	69,429			$	12,363			$	18,068	$	38,998
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	109,301			$	5,857			$	61,747	$	41,697
	Derivatives – Other (C)	8,821				—				8,821		—
		$	118,122			$	5,857			$	70,568	$	41,697
	As of December 31, 2013	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,716			$	8,716			$	—	$	—
	Derivatives – Energy Related Assets (B)	82,778				4,385				27,182		51,211
		$	91,494			$	13,101			$	27,182	$	51,211
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	100,124			$	4,236			$	52,772	$	43,116
	Derivatives – Other (C)	6,676				—				6,676		—
		$	106,800			$	4,236			$	59,448	$	43,116
	(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. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable.
	Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
	Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
	(C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.
	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands):
	Type	Fair Value at September 30, 2014		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets	Liabilities
	Forward Contract - Natural Gas	$30,231	$34,788	Discounted Cash Flow	Forward price (per dt)	$(2.13) - $10.17 [$(0.48)]
	Forward Contract - Electric	$8,767	$6,909	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [55.13%]
					Fixed electric load profile (off-peak)	0.00% - 91.94% [44.87%]
	Type	Fair Value at December 31, 2013						Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets			Liabilities
	Forward Contract - Natural Gas	$	41,444		$	36,043		Discounted Cash Flow	Forward price (per dt)	$(1.75) - $6.05 [$(0.79)]
	Forward Contract - Electric	$	9,767		$	7,073		Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [54.55%]
									Fixed electric load profile (off-peak)	0.00% - 91.94% [45.45%]
	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and nine months ended September 30, 2014 and 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
		Three Months Ended				Nine Months Ended
		30-Sep-14				30-Sep-14
	Balance at beginning of period	$	(4,769	)		$	8,095
	Other changes in fair value from continuing and new contracts, net	(423		)		(14,799		)
	Settlements	2,493				4,005
	Balance at end of period	$	(2,699	)		$	(2,699	)
		Three Months Ended				Nine Months Ended
		30-Sep-13				30-Sep-13
	Balance at beginning of period	(8,515		)		2,762
	Other changes in fair value from continuing and new contracts, net	(8,506		)		(21,229		)
	Transfers in/(out) of Level 3 (A)	2,457				3,385
	Settlements	735				1,253
	Balance at end of period	$	(13,829	)		$	(13,829	)
	(A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the three and nine months ended September 30, 2013, $2.5 million and $3.4 million of net derivatives assets were transferred from Level 2 to Level 3, due to decreased observability of market data. The transfers were recognized as of the end of the second and third quarters of 2013.
	Total losses for 2014 included in earnings for the three and nine months ended September 30, 2014 that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of September 30, 2014, are $0.4 million and$14.8 million, respectively.  These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

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 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.
	We retire debt when it is cost effective as permitted by the debt agreements.  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.
	In June 2014, SJI entered into a Note Purchase Agreement that provided for SJI to issue an aggregate of $240.0 million of medium term notes, all of which were issued as follows:  (a) in June 2014, SJI issued $60.0 million aggregate principal amount of 3.05% Senior Notes due June 2019, and $40.0 million aggregate principal amount of Floating Rate Senior Notes due June 2019; (b) in August 2014, SJI issued $30.0 million aggregate principal amount of 3.05% Senior Notes due August 2019; (c) in September 2014, SJI issued $50.0 million aggregate principal amount of 3.05% Senior Notes due September 2019, and $60.0 million aggregate principal amount of Floating Rate Senior Notes due September 2019. At September 30, 2014, the floating rate was 1.56%.

ACCUMULATED_OTHER_COMPREHENSIV

ACCUMULATED OTHER COMPREHENSIVE LOSS	9 Months Ended
	Sep. 30, 2014
Equity [Abstract]	'
ACCUMULATED OTHER COMPREHENSIVE LOSS	'
	ACCUMULATED OTHER COMPREHENSIVE LOSS:
	The following tables summarize the changes in accumulated other comprehensive loss (AOCL) for the three and nine months ended September 30, 2014 (in thousands):
		Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Other Comprehensive Income (Loss) of Affiliated Companies			Total
	Balance at July 1, 2014 (a)	$	(18,503	)	$	(2,565	)	$	613		$	(57	)	$	(20,512	)
	Other comprehensive income before reclassifications	—			—			(53		)	—			(53		)
	Amounts reclassified from AOCL (b)	—			66			(560		)	63			(431		)
	Net current period other comprehensive income (loss)	—			66			(613		)	63			(484		)
	Balance at September 30, 2014 (a)	$	(18,503	)	$	(2,499	)	$	—		$	6		$	(20,996	)
		Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Other Comprehensive Income (Loss) of Affiliated Companies			Total
	Balance at January 1, 2014 (a)	$	(18,503	)	$	(2,697	)	$	397		$	43		$	(20,760	)
	Other comprehensive income before reclassifications	—			—			163			—			163
	Amounts reclassified from AOCL (b)	—			198			(560		)	(37		)	(399		)
	Net current period other comprehensive income (loss)	—			198			(397		)	(37		)	(236		)
	Balance at September 30, 2014 (a)	$	(18,503	)	$	(2,499	)	$	—		$	6		$	(20,996	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
	The following table provides details about reclassifications out of AOCL for the three and nine months ended September 30, 2014:
		Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Consolidated 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	$	112		$	336		Interest Charges
	Income Taxes	(46		)	(138		)	Income Taxes (a)
		$	66		$	198
	Unrealized Loss on Available-for-Sale Securities	$	(946	)	$	(946	)	Other Income
	Income Taxes	386			386			Income Taxes (a)
		$	(560	)	$	(560	)
	Gain (Loss) of Affiliated Companies	$	107		$	(54	)	Equity in Loss of Affiliated Companies
	Income Taxes	(44		)	17			Income Taxes (a)
		$	63		$	(37	)
	Losses from reclassifications for the period net of tax	$	(431	)	$	(399	)

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
GENERAL	'
	GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy related products and services primarily through the following subsidiaries:
	▪	South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey.
	▪	South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers.
	▪	South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets on a wholesale basis in the mid-Atlantic, Appalachian and southern states.
	▪	South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.
	▪	Marina Energy, LLC (Marina) develops and operates on-site energy-related projects.
	▪	South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.
BASIS OF PRESENTATION	'
	BASIS OF PRESENTATION — The condensed consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management’s opinion, the condensed consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI’s financial position, operating results and cash flows at the dates and for the periods presented. SJI’s businesses are 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 (SEC), the accompanying unaudited condensed consolidated financial statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These financial statements should be read in conjunction with SJI’s 2013 Annual Report on Form 10-K for a more complete discussion of the Company’s 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 in Note 8.
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.
GAS EXPLORATION AND DEVELOPMENT	'
	GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred.
TREASURY STOCK	'
	TREASURY STOCK – SJI uses the par value method of accounting for treasury stock.
INCOME TAXES	'
	INCOME TAXES — Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 740 - “Income Taxes”.  A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow through method, which may result in variations in the customary relationship between income taxes and pre-tax income for interim periods.
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 consolidated financial statements.
	In July 2013, the FASB issued Accounting Standards 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 April 2014, the FASB issued ASU 2014-08 "Presentation of Financial Statements and Property, Plant and Equipment: Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity." This ASU changes the presentation of discontinued operations on the statements of income and other requirements for reporting discontinued operations. Under the new standard, only those disposals of components of an entity that represent a strategic shift that has (or will have) a major effect on an entity's operations and financial results should be reported as a discontinued operation. This ASU also requires additional disclosures about discontinued operations and disposal of an individually significant component of an entity that does not qualify for discontinued operations. The new accounting guidance is effective for interim and annual periods beginning after December 15, 2014, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have 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 services 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. The Company does not expect this standard to have an impact on its consolidated 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. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable.
	Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
	Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
	(C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

STOCKBASED_COMPENSATION_PLAN_T

STOCK-BASED COMPENSATION PLAN (Tables)	9 Months Ended
	Sep. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Summary of the nonvested restricted stock awards outstanding and the assumptions used to estimate the fair value of the awards	'
	The following table summarizes the nonvested restricted stock awards outstanding at September 30, 2014 and the assumptions used to estimate the fair value of the awards:
		Grant Date		Shares Outstanding			Fair Value Per Share				Expected Volatility			Risk-Free Interest Rate
	Officers & Key Employees -	Jan. 2012 - TSR		18,268			$	51.23			22.5	%		0.43	%
		Jan. 2012 - EPS		18,268			$	56.93			N/A			N/A
		Jan. 2013 - TSR		24,797			$	44.38			21.1	%		0.4	%
		Jan. 2013 - EPS		24,797			$	51.18			N/A			N/A
		Jan. 2014 - TSR		31,267			$	44.32			20	%		0.8	%
		Jan. 2014 - EPS		31,267			$	54.44			N/A			N/A
	Directors -	Jan. 2014		11,610			$	54.51			N/A			N/A
Summary of the total stock-based compensation cost for the period	'
	The following table summarizes the total stock-based compensation cost for the three and nine months ended September 30, 2014 and 2013 (in thousands):
		Three Months Ended							Nine Months Ended
		September 30,							September 30,
		2014			2013				2014				2013
	Officers & Key Employees	$	584		$	565			$	1,751			$	1,696
	Directors	159			191				475				574
	Total Cost	743			756				2,226				2,270
	Capitalized	(70		)	(59		)		(210		)		(178		)
	Net Expense	$	673		$	697			$	2,016			$	2,092
Summary of information regarding restricted stock award activity during the period excluding accrued dividend equivalents	'
	The following table summarizes information regarding restricted stock award activity during the nine months ended September 30, 2014, excluding accrued dividend equivalents:
		Officers &Other Key Employees			Directors			Weighted
								Average
								Fair Value
	Nonvested Shares Outstanding, January 1, 2014	94,192			19,617			$	50.73
	Granted	68,453			11,610			$	50.12
	Cancelled/Forfeited	(13,981	)		—			$	49.85
	Vested	—			(19,617	)		$	52.19
	Nonvested Shares Outstanding, September 30, 2014	148,664			11,610			$	50.33

DISCONTINUED_OPERATIONS_AND_AF1

DISCONTINUED OPERATIONS AND AFFILIATIONS (Tables)	9 Months Ended
	Sep. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
Summarized operating results of the discontinued operations	'
	Summarized operating results of the discontinued operations for the three and nine months ended September 30, were (in thousands, except per share amounts):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Loss Before Income Taxes:
	Sand Mining	$	(79	)	$	(287	)	$	(562	)	$	(379	)
	Fuel Oil	(105		)	(22		)	(227		)	(697		)
	Income Tax Benefits	64			109			276			377
	Loss from Discontinued Operations — Net	$	(120	)	$	(200	)	$	(513	)	$	(699	)
	Earnings (Loss) Per Common Share from
	Discontinued Operations — Net:
	Basic and Diluted	—			—			(0.01		)	(0.02		)

COMMON_STOCK_Tables

COMMON STOCK (Tables)	9 Months Ended
	Sep. 30, 2014
Common Stock [Abstract]	'
Common stock shares issued and outstanding	'
	The following shares were issued and outstanding:
		2014
	Beginning Balance, January 1	32,715,042
	New Issues During the Period:
	Dividend Reinvestment Plan	516,050
	Stock-Based Compensation Plan	11,610
	Ending Balance, September 30	33,242,702

SEGMENTS_OF_BUSINESS_Tables

SEGMENTS OF BUSINESS (Tables)	9 Months Ended
	Sep. 30, 2014
Segment Reporting [Abstract]	'
Segments of Business	'
	Information about SJI’s operations in different reportable operating segments is presented below (in thousands):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014				2013
	Operating Revenues:
	Gas Utility Operations	$	60,952		$	59,674		$	340,656			$	300,308
	Energy Group:
	Wholesale Energy Operations	(3,538		)	128			28,898				(4,354		)
	Retail Gas and Other Operations	18,900			19,588			95,281				78,286
	Retail Electric Operations	29,961			36,063			98,233				98,211
	Subtotal Energy Group	45,323			55,779			222,412				172,143
	Energy Services:
	On-Site Energy Production	16,453			14,254			42,196				33,313
	Appliance Service Operations	2,319			2,974			7,610				9,415
	Subtotal Energy Services	18,772			17,228			49,806				42,728
	Corporate & Services	7,001			7,126			21,324				22,968
	Subtotal	132,048			139,807			634,198				538,147
	Intersegment Sales	(9,621		)	(10,999		)	(28,299		)		(31,117		)
	Total Operating Revenues	$	122,427		$	128,808		$	605,899			$	507,030
		Three Months Ended							Nine Months Ended
		September 30,							September 30,
		2014			2013				2014				2013
	Operating Income (Loss):
	Gas Utility Operations	$	3,368		$	3,285			$	75,813			$	69,149
	Energy Group:
	Wholesale Energy Operations	(10,314		)	(8,969		)		(20,437		)		(33,326		)
	Retail Gas and Other Operations	(390		)	(125		)		1,387				(257		)
	Retail Electric Operations	373			(146		)		(521		)		(19		)
	Subtotal Energy Group	(10,331		)	(9,240		)		(19,571		)		(33,602		)
	Energy Services:
	On-Site Energy Production	2,171			111				4,547				(794		)
	Appliance Service Operations	60			532				322				1,317
	Subtotal Energy Services	2,231			643				4,869				523
	Corporate and Services	619			106				1,041				110
	Total Operating (Loss) Income	$	(4,113	)	$	(5,206	)		$	62,152			$	36,180
	Depreciation and Amortization:
	Gas Utility Operations	$	12,942		$	12,476			$	38,375			$	36,429
	Energy Group:
	Wholesale Energy Operations	37			51				123				157
	Retail Gas and Other Operations	19			21				61				64
	Subtotal Energy Group	56			72				184				221
	Energy Services:
	On-Site Energy Production	6,540			4,008				18,480				10,978
	Appliance Service Operations	68			47				202				193
	Subtotal Energy Services	6,608			4,055				18,682				11,171
	Corporate and Services	(41		)	207				413				653
	Total Depreciation and Amortization	$	19,565		$	16,810			$	57,654			$	48,474
	Interest Charges:
	Gas Utility Operations	$	4,046		$	2,629			$	12,680			$	8,379
	Energy Group:
	Wholesale Energy Operations	74			148				190				233
	Retail Gas and Other Operations	43			73				237				216
	Subtotal Energy Group	117			221				427				449
	Energy Services:
	On-Site Energy Production	1,835			1,274				6,110				2,984
	Corporate and Services	2,376			1,488				6,016				4,208
	Subtotal	8,374			5,612				25,233				16,020
	Intersegment Borrowings	(1,606		)	(1,219		)		(4,535		)		(3,499		)
	Total Interest Charges	$	6,768		$	4,393			$	20,698			$	12,521
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014				2013
	Income Taxes:
Gas Utility Operations	$	534		$	471		25,440				23,511
Energy Group:
Wholesale Energy Operations	(3,896		)	(3,616		)	(7,077		)		(13,307		)
Retail Gas and Other Operations	(121		)	(72		)	895				148
Retail Electric Operations	152			(59		)	(213		)		(8		)
Subtotal Energy Group	(3,865		)	(3,747		)	(6,395		)		(13,167		)
Energy Services:
On-Site Energy Production	(5,092		)	(2,547		)	(25,521		)		(20,577		)
Appliance Service Operations	39			232			227				574
Subtotal Energy Services	(5,053		)	(2,315		)	(25,294		)		(20,003		)
Corporate and Services	59			58			283				266
Total Income Taxes	$	(8,325	)	$	(5,533	)	$	(5,966	)		$	(9,393	)
Property Additions:
Gas Utility Operations	$	56,414		$	46,426		$	148,012			$	128,232
Energy Group:
Wholesale Energy Operations	—			8			10				42
Retail Gas and Other Operations	563			7			960				44
Subtotal Energy Group	563			15			970				86
Energy Services:
On-Site Energy Production	22,194			55,737			47,769				73,263
Appliance Service Operations	8			—			14				—
Subtotal Energy Services	22,202			55,737			47,783				73,263
Corporate and Services	1,144			706			2,725				2,570
Total Property Additions	$	80,323		$	102,884		$	199,490			$	204,151
	September 30, 2014			December 31, 2013
Identifiable Assets:
Gas Utility Operations	$	2,058,604		$	1,909,126
Energy Group:
Wholesale Energy Operations	271,304			331,182
Retail Gas and Other Operations	30,956			50,384
Retail Electric Operations	24,325			25,496
Subtotal Energy Group	326,585			407,062
Energy Services:
On-Site Energy Production	614,985			576,315
Appliance Service Operations	2,852			1,812
Subtotal Energy Services	617,837			578,127
Discontinued Operations	1,766			1,068
Corporate and Services	421,466			406,245
Intersegment Assets	(382,575		)	(376,773		)
Total Identifiable Assets	$	3,043,683		$	2,924,855

REGULATORY_ASSETS_REGULATORY_L1

REGULATORY ASSETS & REGULATORY 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	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

PENSION_AND_OTHER_POSTRETIREME1

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	9 Months Ended
	Sep. 30, 2014
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans 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
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Service Cost	$	813		$	1,356		$	3,383		$	4,066
	Interest Cost	2,661			2,360			8,051			7,079
	Expected Return on Plan Assets	(3,262		)	(2,979		)	(9,792		)	(8,936		)
	Amortizations:
	Prior Service Cost	45			63			131			188
	Actuarial Loss	1,398			2,251			4,250			6,754
	Net Periodic Benefit Cost	1,655			3,051			6,023			9,151
	Capitalized Benefit Costs	(577		)	(1,218		)	(2,285		)	(3,653		)
	Total Net Periodic Benefit Expense	$	1,078		$	1,833		$	3,738		$	5,498
		Other Postretirement Benefits
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Service Cost	$	168		$	285		$	668		$	855
	Interest Cost	659			682			2,139			2,047
	Expected Return on Plan Assets	(688		)	(595		)	(2,062		)	(1,784		)
	Amortizations:
	Prior Service Cost (Credits)	38			(71		)	114			(213		)
	Actuarial Loss	245			435			731			1,304
	Net Periodic Benefit Cost	422			736			1,590			2,209
	Capitalized Benefit Costs	(42		)	(286		)	(460		)	(856		)
	Total Net Periodic Benefit Expense	$	380		$	450		$	1,130		$	1,353

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):
	Company	Total Facility		Usage		Available Liquidity		Expiration Date
	SJG:
	Commercial Paper Program/Revolving Credit Facility	$	200,000	$	59,300	$	140,700	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Various
	Total SJG	210,000		59,300		150,700
	SJI:
	Revolving Credit Facility	400,000		103,800		296,200		February 2018 (A)
	Total SJI	400,000		103,800		296,200
	Total	$	610,000	$	163,100	$	446,900
	(A) Includes letters of credit outstanding in the amount of $13.7 million.

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 consolidated 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	$	47,032		$	92,518		$	56,327		$	77,993
	Derivatives – Energy Related – Non-Current	13,384			16,783			26,451			22,131
	Interest rate contracts:
	Derivatives - Other	—			8,821			—			6,676
	Total derivatives not designated as hedging instruments under GAAP	60,416			118,122			82,778			106,800
	Total Derivatives	$	60,416		$	118,122		$	82,778		$	106,800
Offsetting assets and liabilities	'
	As of September 30, 2014 and December 31, 2013, information related to these offsetting arrangements were 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	$	60,416		$	—		$	60,416		$	(27,540	)	(A)	$	—		$	32,876
	Derivatives - Energy Related Liabilities	$	(109,301	)	$	—		$	(109,301	)	$	27,540		(B)	$	33,973		$	(47,788	)
	Derivatives - Other	$	(8,821	)	$	—		$	(8,821	)	$	—			$	—		$	(8,821	)
	As of December 31, 2013
	Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet			Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
											Financial Instruments				Cash Collateral Posted
	Derivatives - Energy Related Assets	$	82,778		$	—		$	82,778		$	(28,082	)	(A)	$	(498	)	$	54,198
	Derivatives - Energy Related Liabilities	$	(100,124	)	$	—		$	(100,124	)	$	28,082		(B)	$	29,639		$	(42,403	)
	Derivatives - Other	$	(6,676	)	$	—		$	(6,676	)	$	—			$	—		$	(6,676	)
	(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 consolidated 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 under GAAP	2014			2013			2014			2013
	Interest Rate Contracts:
	Losses recognized in AOCL on effective portion	$	—		$	—		$	—		$	—
	Losses reclassified from AOCL into income (a)	$	(112	)	$	(112	)	$	(336	)	$	(336	)
	Gains (losses) recognized in income on ineffective portion (a)	$	—		$	—		$	—		$	—
	(a) Included in Interest Charges
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
	Derivatives Not Designated as Hedging Instruments under GAAP	2014			2013			2014			2013
	Losses on energy related commodity contracts (a)	$	(1,633	)	$	(537	)	$	(30,429	)	$	(24,308	)
	Gains (losses) on interest rate contracts (b)	202			390			(103		)	2,165
	Total	$	(1,431	)	$	(147	)	$	(30,532	)	$	(22,143	)
	(a)  Included in Operating Revenues - Non Utility
	(b)  Included in Interest Charges

FAIR_VALUE_OF_FINANCIAL_ASSETS1

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	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)	$	9,013			$	9,013			$	—	$	—
	Derivatives – Energy Related Assets (B)	60,416				3,350				18,068		38,998
		$	69,429			$	12,363			$	18,068	$	38,998
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	109,301			$	5,857			$	61,747	$	41,697
	Derivatives – Other (C)	8,821				—				8,821		—
		$	118,122			$	5,857			$	70,568	$	41,697
	As of December 31, 2013	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,716			$	8,716			$	—	$	—
	Derivatives – Energy Related Assets (B)	82,778				4,385				27,182		51,211
		$	91,494			$	13,101			$	27,182	$	51,211
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	100,124			$	4,236			$	52,772	$	43,116
	Derivatives – Other (C)	6,676				—				6,676		—
		$	106,800			$	4,236			$	59,448	$	43,116
	(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. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable.
	Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
	Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
	(C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.
Quantitative information regarding significant unobservable inputs in Level 3 fair value measurements	'
	The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands):
	Type	Fair Value at September 30, 2014		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets	Liabilities
	Forward Contract - Natural Gas	$30,231	$34,788	Discounted Cash Flow	Forward price (per dt)	$(2.13) - $10.17 [$(0.48)]
	Forward Contract - Electric	$8,767	$6,909	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [55.13%]
					Fixed electric load profile (off-peak)	0.00% - 91.94% [44.87%]
	Type	Fair Value at December 31, 2013						Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets			Liabilities
	Forward Contract - Natural Gas	$	41,444		$	36,043		Discounted Cash Flow	Forward price (per dt)	$(1.75) - $6.05 [$(0.79)]
	Forward Contract - Electric	$	9,767		$	7,073		Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [54.55%]
									Fixed electric load profile (off-peak)	0.00% - 91.94% [45.45%]
Changes in fair value of significant unobservable inputs	'
	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and nine months ended September 30, 2014 and 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
		Three Months Ended				Nine Months Ended
		30-Sep-14				30-Sep-14
	Balance at beginning of period	$	(4,769	)		$	8,095
	Other changes in fair value from continuing and new contracts, net	(423		)		(14,799		)
	Settlements	2,493				4,005
	Balance at end of period	$	(2,699	)		$	(2,699	)
		Three Months Ended				Nine Months Ended
		30-Sep-13				30-Sep-13
	Balance at beginning of period	(8,515		)		2,762
	Other changes in fair value from continuing and new contracts, net	(8,506		)		(21,229		)
	Transfers in/(out) of Level 3 (A)	2,457				3,385
	Settlements	735				1,253
	Balance at end of period	$	(13,829	)		$	(13,829	)
	(A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the three and nine months ended September 30, 2013, $2.5 million and $3.4 million of net derivatives assets were transferred from Level 2 to Level 3, due to decreased observability of market data. The transfers were recognized as of the end of the second and third quarters of 2013.

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 following tables summarize the changes in accumulated other comprehensive loss (AOCL) for the three and nine months ended September 30, 2014 (in thousands):
		Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Other Comprehensive Income (Loss) of Affiliated Companies			Total
	Balance at July 1, 2014 (a)	$	(18,503	)	$	(2,565	)	$	613		$	(57	)	$	(20,512	)
	Other comprehensive income before reclassifications	—			—			(53		)	—			(53		)
	Amounts reclassified from AOCL (b)	—			66			(560		)	63			(431		)
	Net current period other comprehensive income (loss)	—			66			(613		)	63			(484		)
	Balance at September 30, 2014 (a)	$	(18,503	)	$	(2,499	)	$	—		$	6		$	(20,996	)
		Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Other Comprehensive Income (Loss) of Affiliated Companies			Total
	Balance at January 1, 2014 (a)	$	(18,503	)	$	(2,697	)	$	397		$	43		$	(20,760	)
	Other comprehensive income before reclassifications	—			—			163			—			163
	Amounts reclassified from AOCL (b)	—			198			(560		)	(37		)	(399		)
	Net current period other comprehensive income (loss)	—			198			(397		)	(37		)	(236		)
	Balance at September 30, 2014 (a)	$	(18,503	)	$	(2,499	)	$	—		$	6		$	(20,996	)
	(a) Determined using a combined statutory tax rate of 41%.
	(b) See table below.
Reclassifications out of AOCL	'
	The following table provides details about reclassifications out of AOCL for the three and nine months ended September 30, 2014:
		Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Consolidated 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	$	112		$	336		Interest Charges
	Income Taxes	(46		)	(138		)	Income Taxes (a)
		$	66		$	198
	Unrealized Loss on Available-for-Sale Securities	$	(946	)	$	(946	)	Other Income
	Income Taxes	386			386			Income Taxes (a)
		$	(560	)	$	(560	)
	Gain (Loss) of Affiliated Companies	$	107		$	(54	)	Equity in Loss of Affiliated Companies
	Income Taxes	(44		)	17			Income Taxes (a)
		$	63		$	(37	)
	Losses from reclassifications for the period net of tax	$	(431	)	$	(399	)

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Accounting Policies [Abstract]	'	'	'	'	'
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales	$200,000	$100,000	$800,000	$600,000	'
Impairment charges	'	'	0	0	'
Amount of costs related to interests in proved and unproved properties in Pennsylvania, net of amortization	$9,000,000	'	$9,000,000	'	$8,900,000
Shares of treasury stock held (in shares)	130,007	'	130,007	'	148,890

STOCKBASED_COMPENSATION_PLAN_D

STOCK-BASED COMPENSATION PLAN (Details) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2012
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Number of shares in the aggregate that may be issued under the 1997 Stock-Based Compensation Plan	2,000,000	'	2,000,000	'	'
Number of options granted	'	'	0	0	'
Fair value per share (in dollars per share)	$50.33	'	$50.33	'	'
Cost	$743,000	$756,000	$2,226,000	$2,270,000	'
Capitalized	-70,000	-59,000	-210,000	-178,000	'
Net expense	673,000	697,000	2,016,000	2,092,000	'
Unrecognized compensation cost of awards granted under the plan	3,500,000	'	3,500,000	'	'
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	'	'	'1 year 9 months 18 days	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Weighted average fair value nonvested shares-beginning balance (in dollars per share)	'	'	$50.73	'	'
Weighted average fair value nonvested shares-granted during the period (in dollars per share)	'	'	$50.12	'	'
Weighted average fair value nonvested shares-cancelled/forfeited during the period (in dollars per share)	'	'	$49.85	'	'
Weighted average fair value nonvested shares-vested during the period (in dollars per share)	'	'	$52.19	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$50.33	'	$50.33	'	'
Officers and Key Employees	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Number of shares granted	'	'	68,453	56,464	'
The range of the actual amount of shares that ultimately vest of the original share units granted (in hundredths)	'	'	'0% to 150%	'	'
Vesting period of shares (in years)	'	'	'3 years	'	'
Shares outstanding (in shares)	148,664	'	148,664	'	'
Cost	584,000	565,000	1,751,000	1,696,000	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, beginning balance (in shares)	'	'	94,192	'	'
Granted (in shares)	'	'	68,453	56,464	'
Cancelled/Forfeited (in shares)	'	'	-13,981	'	'
Vested (in shares)	'	'	0	'	'
Nonvested shares outstanding, ending balance (in shares)	148,664	'	148,664	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Number of shares awarded during the period	'	'	0	66,077	'
Market value of shares awarded	'	'	'	'	3,300,000
Officers and Key Employees | Grant Date January 2012 - TSR	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Shares outstanding (in shares)	18,268	'	18,268	'	'
Fair value per share (in dollars per share)	$51.23	'	$51.23	'	'
Expected volatility (in hundredths)	'	'	22.50%	'	'
Risk-free interest rate (in hundredths)	'	'	0.43%	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, ending balance (in shares)	18,268	'	18,268	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$51.23	'	$51.23	'	'
Officers and Key Employees | Grant Date January 2012 - EPS	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Shares outstanding (in shares)	18,268	'	18,268	'	'
Fair value per share (in dollars per share)	$56.93	'	$56.93	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, ending balance (in shares)	18,268	'	18,268	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$56.93	'	$56.93	'	'
Officers and Key Employees | Grant Date January 2013 - TSR	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Shares outstanding (in shares)	24,797	'	24,797	'	'
Fair value per share (in dollars per share)	$44.38	'	$44.38	'	'
Expected volatility (in hundredths)	'	'	21.10%	'	'
Risk-free interest rate (in hundredths)	'	'	0.40%	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, ending balance (in shares)	24,797	'	24,797	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$44.38	'	$44.38	'	'
Officers and Key Employees | Grant Date January 2013 - EPS	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Shares outstanding (in shares)	24,797	'	24,797	'	'
Fair value per share (in dollars per share)	$51.18	'	$51.18	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, ending balance (in shares)	24,797	'	24,797	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$51.18	'	$51.18	'	'
Officers and Key Employees | Grant Date January 2014, TSR	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Shares outstanding (in shares)	31,267	'	31,267	'	'
Fair value per share (in dollars per share)	$44.32	'	$44.32	'	'
Expected volatility (in hundredths)	'	'	20.00%	'	'
Risk-free interest rate (in hundredths)	'	'	0.80%	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, ending balance (in shares)	31,267	'	31,267	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$44.32	'	$44.32	'	'
Officers and Key Employees | Grant Date January 2014, EPS	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Shares outstanding (in shares)	31,267	'	31,267	'	'
Fair value per share (in dollars per share)	$54.44	'	$54.44	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, ending balance (in shares)	31,267	'	31,267	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$54.44	'	$54.44	'	'
Directors	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Number of shares granted	'	'	11,610	12,285	'
Vesting period of shares (in years)	'	'	'12 months	'	'
Shares Vested, Directors (in hundredths)	100.00%	'	100.00%	'	'
Shares outstanding (in shares)	11,610	'	11,610	'	'
Cost	159,000	191,000	475,000	574,000	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, beginning balance (in shares)	'	'	19,617	'	'
Granted (in shares)	'	'	11,610	12,285	'
Cancelled/Forfeited (in shares)	'	'	0	'	'
Vested (in shares)	'	'	-19,617	'	'
Nonvested shares outstanding, ending balance (in shares)	11,610	'	11,610	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Market value of shares awarded	'	'	$600,000	$600,000	'
Directors | Grant Date January 2014	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Shares outstanding (in shares)	11,610	'	11,610	'	'
Fair value per share (in dollars per share)	$54.51	'	$54.51	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Nonvested shares outstanding, ending balance (in shares)	11,610	'	11,610	'	'
Additional disclosures [Abstract]	'	'	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$54.51	'	$54.51	'	'
Minimum | Officers and Key Employees	'	'	'	'	'
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 | Officers and Key Employees	'	'	'	'	'
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%	'	'
Stock Appreciation Rights (SARs)	'	'	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'	'	'
Number of shares granted	'	'	0	0	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'	'	'
Granted (in shares)	'	'	0	0	'

DISCONTINUED_OPERATIONS_AND_AF2

DISCONTINUED OPERATIONS AND AFFILIATIONS (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Loss Before Income Taxes:	'	'	'	'
Income Tax Benefits	$64	$109	$276	$377
Loss from Discontinued Operations b Net	-120	-200	-513	-699
Earnings (Loss) Per Common Share from Discontinued Operations b Net	'	'	'	'
Basic and Diluted (in dollars per share)	$0	$0	($0.01)	($0.02)
Sand Mining	'	'	'	'
Loss Before Income Taxes:	'	'	'	'
Loss Before Income Taxes	-79	-287	-562	-379
Fuel Oil	'	'	'	'
Loss Before Income Taxes:	'	'	'	'
Loss Before Income Taxes	($105)	($22)	($227)	($697)

DISCONTINUED_OPERATIONS_AND_AF3

DISCONTINUED OPERATIONS AND AFFILIATIONS 2 (Details) (USD $)	9 Months Ended				1 Months Ended					12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Sep. 30, 2014	Apr. 30, 2012	Dec. 31, 2010	Sep. 30, 2014	Mar. 31, 2013	Apr. 30, 2007	Dec. 31, 2013
				Energenic US LLC	Energenic US LLC	Energenic US LLC	Potato Creek, LLC (Potato Creek)	LVE Energy Partners, LLC (LVE)	LVE Energy Partners, LLC (LVE)	LVE Energy Partners, LLC (LVE)
					Marina Energy LLC	Marina Energy LLC			Marina Energy LLC	LVE Energy Partners
										Marina Energy LLC
Affiliations [Abstract]	'	'	'	'	'	'	'	'	'	'
Equity interest (in hundredths)	'	'	'	50.00%	'	50.00%	30.00%	50.00%	50.00%	'
Advances to affiliates for acquisition	$3,472,000	$11,849,000	'	'	$35,400,000	'	'	'	'	'
Proceeds from sale of joint venture	'	'	'	'	'	'	'	'	'	57,900,000
Investments in unconsolidated affiliates	1,300,000	12,900,000	'	'	'	'	'	'	'	'
Notes Receivable - affiliate	47,700,000	'	48,800,000	'	'	'	'	'	'	'
Interest accrual on secured notes receivable (in hundredths)	7.50%	'	'	'	'	'	'	'	'	'
Net asset - included in investment in affiliates and other noncurrent liabilities	72,000,000	'	'	'	'	'	'	'	'	'
Combined equity contributions and the notes receivable - affiliate	$120,600,000	'	'	'	'	'	'	'	'	'

COMMON_STOCK_Details

COMMON STOCK (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Common Stock [Roll Forward]	'	'	'	'
Beginning balance (in shares)	'	'	32,715,042	'
New issues during period [Abstract]	'	'	'	'
Dividend reinvestment plan (in shares)	'	'	516,050	'
Stock-based compensation plan (in shares)	'	'	11,610	'
Ending balance (in shares)	33,242,702	'	33,242,702	'
Par value of common stock (in dollars per share)	$1.25	'	$1.25	'
Net excess over par value recorded in premium on common stock	'	'	$30,200,000	'
Incremental shares included in diluted earnings per share (in shares)	74,332	67,196	75,296	61,315
Proceeds from sale of common stock	'	'	$29,125,000	$13,931,000

FINANCIAL_INSTRUMENTS_Details

FINANCIAL INSTRUMENTS (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Restricted investments held In escrow	$1.40	$1.30
Margin accounts with selected counterparties to support risk management activities	46.5	41.8
South Jersey Gas Company | Financing Receivable	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Long-term receivables, net of unamortized discount	14.9	15
Imputed interest on long term receivables	$1.20	$1.30

FINANCIAL_INSTRUMENTS_2_Detail

FINANCIAL INSTRUMENTS 2 (Details) (Derivatives Energy Related Assets, Supplier Concentration Risk, USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
Derivatives Energy Related Assets | Supplier Concentration Risk	'
Concentration Risk [Line Items]	'
Amount of derivatives - energy related assets with single retail counterparty	$19.30
Percentage of derivatives - energy related assets with a single retail counterparty (in hundredths)	31.90%

FINANCIAL_INSTRUMENTS_3_Detail

FINANCIAL INSTRUMENTS 3 (Details) (USD $)	9 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2013	Dec. 31, 2010
Schedule of Equity Method Investments [Line Items]	'	'	'
Finance obligation to ACB Energy Partners LLC	$19,916,000	$20,656,000	'
Estimated fair value of long-term debt	1,041,900,000	713,200,000	'
Carrying amount of long-term debt	1,009,400,000	701,400,000	'
Energenic US LLC	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity interest of Marina in Energenic (in hundredths)	50.00%	'	'
Marina Energy LLC | Energenic US LLC	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity interest of Marina in Energenic (in hundredths)	'	'	50.00%
Other construction costs	$23,700,000	$23,700,000	'

SEGMENTS_OF_BUSINESS_Details

SEGMENTS OF BUSINESS (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	Dec. 31, 2013
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	$122,427	$128,808	$605,899	$507,030	'
Operating Income (Loss)	-4,113	-5,206	62,152	36,180	'
Depreciation and Amortization	19,565	16,810	57,654	48,474	'
Interest Charges	6,768	4,393	20,698	12,521	'
Income Taxes	-8,325	-5,533	-5,966	-9,393	'
Property Additions	80,323	102,884	199,490	204,151	'
Identifiable Assets	3,043,683	'	3,043,683	'	2,924,855
Operating Segments	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	132,048	139,807	634,198	538,147	'
Interest Charges	8,374	5,612	25,233	16,020	'
Operating Segments | Gas Utility Operations	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	60,952	59,674	340,656	300,308	'
Operating Income (Loss)	3,368	3,285	75,813	69,149	'
Depreciation and Amortization	12,942	12,476	38,375	36,429	'
Interest Charges	4,046	2,629	12,680	8,379	'
Income Taxes	534	471	25,440	23,511	'
Property Additions	56,414	46,426	148,012	128,232	'
Identifiable Assets	2,058,604	'	2,058,604	'	1,909,126
Operating Segments | Energy Group	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	45,323	55,779	222,412	172,143	'
Operating Income (Loss)	-10,331	-9,240	-19,571	-33,602	'
Depreciation and Amortization	56	72	184	221	'
Interest Charges	117	221	427	449	'
Income Taxes	-3,865	-3,747	-6,395	-13,167	'
Property Additions	563	15	970	86	'
Identifiable Assets	326,585	'	326,585	'	407,062
Operating Segments | Energy Group | Wholesale Energy Operations	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	-3,538	128	28,898	-4,354	'
Operating Income (Loss)	-10,314	-8,969	-20,437	-33,326	'
Depreciation and Amortization	37	51	123	157	'
Interest Charges	74	148	190	233	'
Income Taxes	-3,896	-3,616	-7,077	-13,307	'
Property Additions	0	8	10	42	'
Identifiable Assets	271,304	'	271,304	'	331,182
Operating Segments | Energy Group | Retail Gas and Other Operations	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	18,900	19,588	95,281	78,286	'
Operating Income (Loss)	-390	-125	1,387	-257	'
Depreciation and Amortization	19	21	61	64	'
Interest Charges	43	73	237	216	'
Income Taxes	-121	-72	895	148	'
Property Additions	563	7	960	44	'
Identifiable Assets	30,956	'	30,956	'	50,384
Operating Segments | Energy Group | Retail Electric Operations	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	29,961	36,063	98,233	98,211	'
Operating Income (Loss)	373	-146	-521	-19	'
Income Taxes	152	-59	-213	-8	'
Identifiable Assets	24,325	'	24,325	'	25,496
Operating Segments | Energy Services	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	18,772	17,228	49,806	42,728	'
Operating Income (Loss)	2,231	643	4,869	523	'
Depreciation and Amortization	6,608	4,055	18,682	11,171	'
Income Taxes	-5,053	-2,315	-25,294	-20,003	'
Property Additions	22,202	55,737	47,783	73,263	'
Identifiable Assets	617,837	'	617,837	'	578,127
Operating Segments | Energy Services | On-site Energy Production	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	16,453	14,254	42,196	33,313	'
Operating Income (Loss)	2,171	111	4,547	-794	'
Depreciation and Amortization	6,540	4,008	18,480	10,978	'
Interest Charges	1,835	1,274	6,110	2,984	'
Income Taxes	-5,092	-2,547	-25,521	-20,577	'
Property Additions	22,194	55,737	47,769	73,263	'
Identifiable Assets	614,985	'	614,985	'	576,315
Operating Segments | Energy Services | Appliance Service Operations	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	2,319	2,974	7,610	9,415	'
Operating Income (Loss)	60	532	322	1,317	'
Depreciation and Amortization	68	47	202	193	'
Income Taxes	39	232	227	574	'
Property Additions	8	0	14	0	'
Identifiable Assets	2,852	'	2,852	'	1,812
Operating Segments | Corporate and Services	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	7,001	7,126	21,324	22,968	'
Operating Income (Loss)	619	106	1,041	110	'
Depreciation and Amortization	-41	207	413	653	'
Interest Charges	2,376	1,488	6,016	4,208	'
Income Taxes	59	58	283	266	'
Property Additions	1,144	706	2,725	2,570	'
Identifiable Assets	421,466	'	421,466	'	406,245
Discontinued Operations	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Identifiable Assets	1,766	'	1,766	'	1,068
Intersegment Elimination	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Operating Revenues	-9,621	-10,999	-28,299	-31,117	'
Interest Charges	-1,606	-1,219	-4,535	-3,499	'
Identifiable Assets	($382,575)	'	($382,575)	'	($376,773)

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]	'	'	'	'	'	'	'	'	'	'	'
Approved base rate increase	'	'	$20	$7.50	'	'	'	'	'	'	'
Rate of return on base rate	'	'	7.10%	'	'	'	'	'	'	'	'
Return on common equity	'	'	9.75%	'	'	'	'	'	'	'	'
Costs requested for deferral, storm related	'	0	'	'	'	'	'	'	'	'	'
Public utilities, annual depreciation reduction attributable to petition	'	'	0	'	'	'	'	'	'	'	'
Amount of regulatory costs approved, percent change in recoveries	'	'	'	'	0.19%	'	'	'	'	'	'
Increase (decrease) in amount of regulatory costs approved	'	'	'	'	'	2.2	-6.4	4.9	'	7.9	'
Proposed recovery period (in years)	'	'	'	'	'	'	'	'2 years	'	'	'
Amount of regulatory costs approved, statewide	'	'	'	'	'	'	'	'	'	71.8	'
Amount of regulatory costs not yet approved, annual revenue impact	'	'	'	'	'	'	'	'	'	'	2.6
Investment requested to be recovered through SHARP	103.5	'	'	'	'	'	'	'	'	'	'
Investment requested to be recovered through SHARP, term	'3 years	'	'	'	'	'	'	'	'	'	'
BGSS refunds made to customers	'	'	'	'	'	'	'	'	$11.20	'	'

REGULATORY_ASSETS_REGULATORY_L2

REGULATORY ASSETS & REGULATORY 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_REGULATORY_L3

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

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	'	$813,000	$1,356,000	$3,383,000	$4,066,000
Interest Cost	'	2,661,000	2,360,000	8,051,000	7,079,000
Expected return on plan assets	'	-3,262,000	-2,979,000	-9,792,000	-8,936,000
Amortizations [Abstract]	'	'	'	'	'
Prior service cost (credits)	'	45,000	63,000	131,000	188,000
Actuarial loss	'	1,398,000	2,251,000	4,250,000	6,754,000
Net Periodic Benefit Cost	'	1,655,000	3,051,000	6,023,000	9,151,000
Capitalized benefit costs	'	-577,000	-1,218,000	-2,285,000	-3,653,000
Total net periodic benefit expense	'	1,078,000	1,833,000	3,738,000	5,498,000
Contributions	12,700,000	'	'	'	'
Other Postretirement Benefits	'	'	'	'	'
Net periodic benefit cost [Abstract]	'	'	'	'	'
Service Cost	'	168,000	285,000	668,000	855,000
Interest Cost	'	659,000	682,000	2,139,000	2,047,000
Expected return on plan assets	'	-688,000	-595,000	-2,062,000	-1,784,000
Amortizations [Abstract]	'	'	'	'	'
Prior service cost (credits)	'	38,000	-71,000	114,000	-213,000
Actuarial loss	'	245,000	435,000	731,000	1,304,000
Net Periodic Benefit Cost	'	422,000	736,000	1,590,000	2,209,000
Capitalized benefit costs	'	-42,000	-286,000	-460,000	-856,000
Total net periodic benefit expense	'	380,000	450,000	1,130,000	1,353,000
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	'	'	'	$1,300,000	'

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	$610,000,000		'
Usage	163,100,000		'
Available liquidity	446,900,000		'
Letters of credit outstanding	13,700,000		'
Weighted average borrowing cost	0.83%		0.98%
Average borrowings outstanding during the period	291,600,000		297,200,000
Maximum amounts outstanding during the period	390,700,000		389,400,000
Financial covenant, ratio of indebtedness to consolidated total capitalization	'0.65 to 1		'
Minimum	'		'
Line of Credit Facility [Line Items]	'		'
Financial covenant, ratio of indebtedness to consolidated total capitalization minimum	0.65		'
SJG 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		'
South Jersey Gas Company	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	210,000,000		'
Usage	59,300,000		'
Available liquidity	150,700,000		'
South Jersey Gas Company | 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		'
South Jersey Gas Company | 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 Industries Inc	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	400,000,000		'
Usage	103,800,000		'
Available liquidity	296,200,000		'
South Jersey Industries Inc | Revolving Credit Facility	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	400,000,000	[1]	'
Usage	103,800,000	[1]	'
Available liquidity	$296,200,000	[1]	'
Expiration date	'February 2018 (A)	[1]	'
[1]	Includes letters of credit outstanding in the amount of $13.7 million.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

31-May-12

31-May-12

Sep. 30, 2014

Mar. 31, 2013

Apr. 30, 2007

Dec. 31, 2013

unions

sites

Letter of Credit, Developer

Standby Letter of Credit

Letter of Credit, Separate Facility

LVE Energy Partners

LVE Energy Partners

Energenic

Energenic

Energenic

Parental Guarantee

LVE Energy Partners, LLC (LVE)

Marina Energy LLC

Marina Energy LLC

UMM Energy Partners, LLC

UMM Energy Partners, LLC

LVE Energy Partners, LLC (LVE)

LVE Energy Partners, LLC (LVE)

Maximum

LVE Energy Partners

Guarantees [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability recorded related to guarantees

$700,000

'

'

'

'

'

$800,000

$400,000

'

'

'

'

'

'

Equity interest (in hundredths)

'

'

'

'

'

'

'

50.00%

'

'

'

50.00%

50.00%

'

Contract with a resort developer (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'25 years

'

Proceeds from sale of joint venture

'

'

'

'

'

'

'

'

'

'

'

'

'

57,900,000

Notes Receivable

7,882,000

7,882,000

'

'

'

'

'

'

'

'

'

'

'

'

Maximum amount of obligation under guarantee contracts

4,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Notes receivable - affiliate

9,213,000

8,908,000

'

'

'

9,000,000

'

'

'

'

'

'

'

'

Letter of credit provided

610,000,000

'

5,000,000

13,700,000

87,600,000

'

'

'

'

'

'

'

'

'

Contract term (in years)

'

'

'

'

'

'

'

'

'30 years

'

'

'

'

'

Annual obligations under the agreement

'

'

'

'

'

'

'

'

'

2,200,000

'

'

'

'

Guaranteed amount

'

'

'

'

'

'

'

'

'

'

5,800,000

'

'

'

Collective bargaining agreements [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

45.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of unions (in unions)

2

'

'

'

'

'

'

'

'

'

'

'

'

'

Pending litigation [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated litigation liability

3,000,000

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Environmental remediation costs [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

12

'

'

'

'

'

'

'

'

'

'

'

'

Investment in Affiliates

72,866,000

78,273,000

'

'

'

'

'

23,300,000

'

'

'

'

'

'

Notes Receivable-Affiliate

$38,527,000

$39,907,000

'

'

'

'

'

$13,700,000

'

'

'

'

'

'

DERIVATIVE_INSTRUMENTS_Details

DERIVATIVE INSTRUMENTS (Details)	Sep. 30, 2014
	millions_of_decatherms
Basis and Index Related Purchase and Sales Contracts	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	164.1
Natural Gas (in MMdts) | Derivative Transaction Type, Purchase	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	42.3
Natural Gas (in MMdts) | Derivative Transaction Type, Sale	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	35.6
Electricity (in MMmwh) | Derivative Transaction Type, Purchase	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	900,000
Electricity (in MMmwh) | Derivative Transaction Type, Sale	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	1,000,000

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	$60,416	$82,778
Fair value Derivative Liabilities	118,122	106,800
Not Designated as Hedging Instrument	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	60,416	82,778
Fair value Derivative Liabilities	118,122	106,800
Commodity Contract | Not Designated as Hedging Instrument | Derivatives-Energy Related-Current	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	47,032	56,327
Fair value Derivative Liabilities	92,518	77,993
Commodity Contract | Not Designated as Hedging Instrument | Derivatives-Energy Related-NonCurrent	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	13,384	26,451
Fair value Derivative Liabilities	16,783	22,131
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	$8,821	$6,676

DERIVATIVE_INSTRUMENTS_3_Detai

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	$60,416		$82,778
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	60,416		82,778
Gross amounts not offset in the balance sheet, Financial Instruments	-27,540	[1]	-28,082	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		-498
Net amount	32,876		54,198
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-109,301		-100,124
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-109,301		-100,124
Gross amounts not offset in the balance sheet, Financial Instruments	27,540	[2]	28,082	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	33,973		29,639
Net amount	-47,788		-42,403
Interest Rate Contract	'		'
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-8,821		-6,676
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-8,821		-6,676
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	($8,821)		($6,676)
[1]	The balances at SeptemberB 30, 2014 and DecemberB 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at SeptemberB 30, 2014 and DecemberB 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
Interest Rate Contracts [Abstract]	'		'		'		'
Losses recognized in AOCL on effective portion	$0		$0		$0		$0
Losses reclassified from AOCL into income	-112,000	[1]	-112,000	[1]	-336,000	[1]	-336,000	[1]
Gains (losses) recognized in income on ineffective portion	0	[1]	0	[1]	0	[1]	0	[1]
Total	-1,431,000		-147,000		-30,532,000		-22,143,000
Net realized gains (losses), derivative instruments, energy-related contracts	1,200,000		400,000		-2,400,000		600,000
Fair value derivative instruments with credit-risk-related features	33,100,000		'		33,100,000		'
Additional collateral, aggregate fair value	24,500,000		'		24,500,000		'
Not Designated as Hedging Instrument	'		'		'		'
Interest Rate Contracts [Abstract]	'		'		'		'
Losses on energy related commodity contracts	-1,633,000	[2]	-537,000	[2]	-30,429,000	[2]	-24,308,000	[2]
(Losses) gains on interest rate contracts	$202,000	[1]	$390,000	[1]	($103,000)	[1]	$2,165,000	[1]
[1]	Included in Interest Charges
[2]	Included in Operating Revenues - Non Utility

FAIR_VALUE_OF_FINANCIAL_ASSETS2

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

3 Months Ended

9 Months Ended

In Thousands, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Fair Value, Measurements, Recurring

Total [Member]

Total [Member]

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Assets [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Available-for-Sale Securities

'

'

'

'

$9,013

[1]

$8,716

[1]

$9,013

[1]

$8,716

[1]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

Derivatives - Energy Related Assets

'

'

'

'

60,416

[2]

82,778

[2]

3,350

[2]

4,385

[2]

18,068

[2]

27,182

[2]

38,998

[2]

51,211

[2]

Total Assets

'

'

'

'

69,429

91,494

12,363

13,101

18,068

27,182

38,998

51,211

Liabilities [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Derivatives - Energy Related Liabilities

'

'

'

'

109,301

[2]

100,124

[2]

5,857

[2]

4,236

[2]

61,747

[2]

52,772

[2]

41,697

[2]

43,116

[2]

Derivatives - Other

'

'

'

'

8,821

[3]

6,676

[3]

0

[3]

0

[3]

8,821

[3]

6,676

[3]

0

[3]

0

[3]

Total Liabilities

'

'

'

'

118,122

106,800

5,857

4,236

70,568

59,448

41,697

43,116

Changes in significant unobservable inputs [Roll forward]

'

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period

-4,769

-8,515

8,095

2,762

'

'

'

'

'

'

'

'

Other changes in fair value from continuing and new contracts, net

-423

-8,506

-14,799

-21,229

'

'

'

'

'

'

'

'

Transfers in/(out) of Level 3

'

2,457

[4]

'

3,385

[4]

'

'

'

'

'

'

'

'

Settlements

2,493

735

4,005

1,253

'

'

'

'

'

'

'

'

Balance at end of period

($2,699)

($13,829)

($2,699)

($13,829)

'

'

'

'

'

'

'

'

[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. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.

[3]

Derivatives b Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

[4]

Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the three and nine months ended SeptemberB 30, 2013, $2.5 million and $3.4 million of net derivatives assets were transferred from Level 2 to Level 3, due to decreased observability of market data. The transfers were recognized as of the end of the second and third quarters of 2013.

FAIR_VALUE_OF_FINANCIAL_ASSETS3

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES, LEVEL THREE INPUTS (Details) (Forward Contracts, Fair Value, Inputs, Level 3, USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Natural Gas	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Assets	$30,231	$41,444
Liabilities	34,788	36,043
Electricity	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Assets	8,767	9,767
Liabilities	$6,909	$7,073
Minimum | Natural Gas	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Forward price (in dollars per dt)	-2.13	-1.75
Maximum | Natural Gas	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Forward price (in dollars per dt)	10.17	6.05
Weighted Average | Natural Gas	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Forward price (in dollars per dt)	-0.48	-0.79
On-Peak | Minimum | Electricity	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	8.06%	8.06%
On-Peak | Maximum | Electricity	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	100.00%	100.00%
On-Peak | Weighted Average | Electricity	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	55.13%	54.55%
Off-Peak | Minimum | Electricity	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	0.00%	0.00%
Off-Peak | Maximum | Electricity	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	91.94%	91.94%
Off-Peak | Weighted Average | Electricity	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	44.87%	45.45%

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Jul. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Jan. 31, 2014

Jun. 30, 2014

Jun. 30, 2014

Sep. 30, 2014

Jun. 30, 2014

Aug. 31, 2014

Jun. 30, 2014

Sep. 30, 2014

Jun. 30, 2014

Sep. 30, 2014

South Jersey Gas Company

South Jersey Gas Company

South Jersey Gas Company

South Jersey Gas Company

South Jersey Gas Company

Mortgages

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Medium-term notes

Medium-term notes

Line of Credit

Line of Credit

Series Due January 2030, 4.23%

June 2014 Note Purchase Agreement

Series Due Jun 2019, 3.05%

Series Due June 2019, Floating Rate

Series Due June 2019, Floating Rate

Series Due Aug 2019, 3.05%

Series Due Aug 2019, 3.05%

Series Due Sept 2019, 3.05%

Series Due Sept 2019, 3.05%

Series Due Sept 2019, Floating Rate

South Jersey Gas Company

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt face amount

'

'

'

'

'

'

'

$30,000,000

$240,000,000

$60,000,000

'

$40,000,000

$30,000,000

'

$50,000,000

'

$60,000,000

Stated interest rate

7.50%

'

'

5.12%

4.52%

'

'

4.23%

'

3.05%

'

'

'

3.05%

'

3.05%

'

Credit facility borrowing capacity

610,000,000

'

210,000,000

'

'

'

200,000,000

'

'

'

'

'

'

'

'

'

'

Carrying amount of long-term debt

1,009,400,000

701,400,000

'

'

'

59,000,000

'

'

'

'

'

'

'

'

'

'

'

Debt retired

'

'

'

$10,000,000

$11,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Floating rate

'

'

'

'

'

'

'

'

'

'

1.56%

'

'

'

'

'

'

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	($20,512)	[1]	'		($20,760)	[1]	'
Other comprehensive income before reclassifications	-53		'		163		'
Amounts reclassified from AOCL	-431	[2]	'		-399	[2]	'
Other Comprehensive (Loss) Income - Net of Tax	-484	[1]	262	[1]	-236	[1]	5,133	[1]
Ending balance	-20,996	[1]	'		-20,996	[1]	'
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	-18,503	[1]	'		-18,503	[1]	'
Other comprehensive income before reclassifications	0		'		0		'
Amounts reclassified from AOCL	0	[2]	'		0	[2]	'
Other Comprehensive (Loss) Income - Net of Tax	0		'		0		'
Ending balance	-18,503	[1]	'		-18,503	[1]	'
Unrealized Gain (Loss) on Derivatives-Other	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	-2,565	[1]	'		-2,697	[1]	'
Other comprehensive income before reclassifications	0		'		0		'
Amounts reclassified from AOCL	66	[2]	'		198	[2]	'
Other Comprehensive (Loss) Income - Net of Tax	66		'		198		'
Ending balance	-2,499	[1]	'		-2,499	[1]	'
Unrealized Gain (Loss) on Available-for-Sale Securities	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	613	[1]	'		397	[1]	'
Other comprehensive income before reclassifications	-53		'		163		'
Amounts reclassified from AOCL	-560	[2]	'		-560	[2]	'
Other Comprehensive (Loss) Income - Net of Tax	-613		'		-397		'
Ending balance	0	[1]	'		0	[1]	'
Other Comprehensive Income (Loss) of Affiliated Companies	'		'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'		'
Beginning balance	-57	[1]	'		43	[1]	'
Other comprehensive income before reclassifications	0		'		0		'
Amounts reclassified from AOCL	63	[2]	'		-37	[2]	'
Other Comprehensive (Loss) Income - Net of Tax	63		'		-37		'
Ending balance	$6	[1]	'		$6	[1]	'
[1]	Determined using a combined statutory tax rate of 41%.
[2]	See table below.

ACCUMULATED_OTHER_COMPREHENSIV3

ACCUMULATED OTHER COMPREHENSIVE LOSS 2 (Details) (USD $)	3 Months Ended			9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Interest Charges	$6,768		$4,393	$20,698		$12,521
Nonoperating Income (Expense)	-3,419		-2,200	-9,972		-8,734
Equity in Gain (Loss) of Affiliated Companies	5,139		-645	3,756		-1,246
Income Taxes	-8,325		-5,533	-5,966		-9,393
(Loss) Income from Continuing Operations	4,276		1,221	-53,636		-43,032
Reclassification out of Accumulated Other Comprehensive Income	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
(Loss) Income from Continuing Operations	-431		'	-399		'
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Gain (Loss) on Derivatives-Other	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Interest Charges	112		'	336		'
Income Taxes	-46	[1]	'	-138	[1]	'
(Loss) Income from Continuing Operations	66		'	198		'
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Loss on Available-for-Sale Securities	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Nonoperating Income (Expense)	-946		'	-946		'
Income Taxes	386	[1]	'	386	[1]	'
(Loss) Income from Continuing Operations	-560		'	-560		'
Reclassification out of Accumulated Other Comprehensive Income | Other Comprehensive Income (Loss) of Affiliated Companies	'		'	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'	'		'
Equity in Gain (Loss) of Affiliated Companies	107		'	-54		'
Income Taxes	-44	[1]	'	17	[1]	'
(Loss) Income from Continuing Operations	$63		'	($37)		'
[1]	Determined using a combined statutory tax rate of 41%.