South Jersey Industries (SJIIU) 10-Q 9 May 14 2014 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	3 Months Ended
	Mar. 31, 2014	1-May-14
Entity Information [Line Items]	'	'
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	31-Mar-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q1	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	32,978,971

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating Revenues:	'	'
Utility	$210,329	$173,651
Nonutility	139,872	81,980
Total Operating Revenues	350,201	255,631
Cost of Sales - (Excluding depreciation)	'	'
- Utility	103,077	77,156
- Nonutility	125,061	75,145
Operations	39,350	32,689
Maintenance	3,259	3,422
Depreciation	14,991	11,407
Energy and Other Taxes	1,953	3,833
Total Operating Expenses	287,691	203,652
Operating Income	62,510	51,979
Other Income and Expense	2,368	3,869
Interest Charges	-7,084	-4,708
Income Before Income Taxes	57,794	51,140
Income Tax Benefit (Expense)	-11,869	-7,772
Equity in Earnings (Loss) of Affiliated Companies	2,286	-31
Income from Continuing Operations	48,211	43,337
Loss from Discontinued Operations - (Net of tax benefit)	-313	-471
Net Income	$47,898	$42,866
Basic Earnings Per Common Share:	'	'
Continuing Operations (in dollars per share)	$1.47	$1.36
Discontinued Operations (in dollars per share)	($0.01)	($0.01)
Basic Earnings Per Common Share (in dollars per share)	$1.46	$1.35
Average Shares of Common Stock Outstanding - Basic (in shares)	32,765	31,757
Diluted Earnings Per Common Share:	'	'
Continuing Operations (in dollars per share)	$1.47	$1.36
Discontinued Operations (in dollars per share)	($0.01)	($0.01)
Diluted Earnings Per Common Share (in dollars per share)	$1.46	$1.35
Average Shares of Common Stock Outstanding - Diluted (in shares)	32,842	31,811
Dividends Declared per Common Share (in dollars per share)	$0.47	$0.44

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Statement of Other Comprehensive Income [Abstract]	'		'
Net Income	$47,898		$42,866
Other Comprehensive Income, Net of Tax:	'		'
Unrealized Gain (Loss) on Available-for-Sale Securities	62	[1]	-274	[1]
Unrealized Gain on Derivatives - Other	66	[1]	66	[1]
Other Comprehensive Income (Loss) of Affiliated Companies	-18	[1]	5,014	[1]
Other Comprehensive Income - Net of Tax	110	[1]	4,806	[1]
Comprehensive Income	$48,008		$47,672
[1]	Determined using a combined statutory tax rate of 41%.

CONDENSED_CONSOLIDATED_STATEME2

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

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Statement of Cash Flows [Abstract]	'	'
Net Cash Provided by Operating Activities	$49,232	$55,886
Cash Flows from Investing Activities:	'	'
Capital Expenditures	-60,254	-40,604
Net Proceeds from Sale of Restricted Investments in Margin Account	7,444	7,931
Investment in Long-Term Receivables	-2,053	-1,947
Proceeds from Long-Term Receivables	1,981	2,402
Purchase of Company Owned Life Insurance	-230	-372
Investment in Affiliate	0	-1,076
Advances on Notes Receivable - Affiliate	-342	-498
Repayment of Notes Receivable - Affiliate	3,228	58,249
Net Cash (Used in) Provided by Investing Activities	-50,226	24,085
Cash Flows from Financing Activities:	'	'
Net Repayments of Short-Term Credit Facilities	-29,600	-90,500
Proceeds from Issuance of Long-Term Debt	30,000	0
Payments for Issuance of Long-Term Debt	-210	-11
Proceeds from Sale of Common Stock	5,157	7,244
Net Cash Provided by (Used in) Financing Activities	5,347	-83,267
Net Increase (Decrease) in Cash and Cash Equivalents	4,353	-3,296
Cash and Cash Equivalents at Beginning of Period	3,818	4,638
Cash and Cash Equivalents at End of Period	$8,171	$1,342

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment:	'		'
Utility Plant, at original cost	$1,846,704		$1,816,804
Accumulated Depreciation	-398,954		-392,029
Nonutility Property and Equipment, at cost	495,433		486,332
Accumulated Depreciation	-57,968		-52,009
Property, Plant and Equipment - Net	1,885,215		1,859,098
Investments:	'		'
Available-for-Sale Securities	8,829		8,716
Restricted	35,670		43,115
Investment in Affiliates	80,324		78,273
Total Investments	124,823		130,104
Current Assets:	'		'
Cash and Cash Equivalents	8,171		3,818
Accounts Receivable	362,675		253,566
Unbilled Revenues	53,841		47,594
Provision for Uncollectibles	-6,725		-5,854
Notes Receivable - Affiliate	6,536		8,908
Natural Gas in Storage, average cost	15,299		57,786
Materials and Supplies, average cost	2,851		2,798
Deferred Income Taxes - Net	23,978		30,609
Prepaid Taxes	1,220		9,431
Derivatives - Energy Related Assets	58,123		56,327
Other Prepayments and Current Assets	25,248		17,915
Total Current Assets	551,217		482,898
Regulatory and Other Noncurrent Assets:	'		'
Regulatory Assets	309,290		296,081
Derivatives - Energy Related Assets	18,439		26,451
Unamortized Debt Issuance Costs	8,732		7,803
Notes Receivables-Affiliate	39,563		39,907
Contract Receivables	14,554		14,595
Notes Receivable	7,882		7,882
Other	60,086		60,036
Total Regulatory and Other Noncurrent Assets	458,546		452,755
Total Assets	3,019,801		2,924,855
Equity:	'		'
Common Stock	41,028		40,894
Premium on Common Stock	406,397		401,011
Treasury Stock (at par)	-162		-186
Accumulated Other Comprehensive Loss	-20,650	[1]	-20,760	[1]
Retained Earnings	438,429		406,041
Total Equity	865,042		827,000
Long-Term Debt	710,400		680,400
Total Capitalization	1,575,442		1,507,400
Current Liabilities:	'		'
Notes Payable	324,300		353,900
Current Portion of Long-Term Debt	21,000		21,000
Accounts Payable	295,730		259,757
Customer Deposits and Credit Balances	15,112		15,546
Environmental Remediation Costs	27,184		16,695
Taxes Accrued	9,677		3,234
Derivatives - Energy Related Liabilities	89,892		77,993
Dividends Payable	15,510		0
Interest Accrued	6,219		6,363
Pension Benefits	1,241		1,275
Other Current Liabilities	6,858		9,210
Total Current Liabilities	812,723		764,973
Deferred Credits and Other Noncurrent Liabilities:	'		'
Deferred Income Taxes - Net	321,827		319,368
Investment Tax Credits	307		360
Pension and Other Postretirement Benefits	58,776		57,370
Environmental Remediation Costs	96,708		106,734
Asset Retirement Obligations	41,925		41,687
Derivatives - Energy Related Liabilities	20,274		22,131
Derivatives - Other	7,890		6,676
Regulatory Liabilities	48,158		60,949
Finance Obligation	20,420		20,656
Other	15,351		16,551
Total Deferred Credits and Other Noncurrent Liabilities	631,636		652,482
Commitments and Contingencies (Note 11)	'		'
Total Capitalization and Liabilities	$3,019,801		$2,924,855
[1]	Determined using a combined statutory tax rate of 41%.

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:
	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 $0.4 million for both the three months ended March 31, 2014 and 2013. In prior years, SJG had collected a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). The TEFA was eliminated effective January 1, 2014.
	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 three months ended March 31, 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 three months ended March 31, 2014 or 2013. As of both March 31, 2014 and December 31, 2013, $8.9 million 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 March 31, 2014 and December 31, 2013, SJI held 129,929 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.

STOCKBASED_COMPENSATION_PLAN

STOCK-BASED COMPENSATION PLAN	3 Months Ended
	Mar. 31, 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 three months ended March 31, 2014 and 2013.  No stock appreciation rights have been issued under the plan. During the three months ended March 31, 2014 and 2013, SJI granted 67,874 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 three months ended March 31, 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 March 31, 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		18,640			$	51.23		22.5	%	0.43	%
		Jan. 2012 - EPS		18,640			$	56.93		N/A		N/A
		Jan. 2013 - TSR		25,898			$	44.38		21.1	%	0.4	%
		Jan. 2013 - EPS		25,898			$	51.18		N/A		N/A
		Jan. 2014 - TSR		32,686			$	44.32		20	%	0.8	%
		Jan. 2014 - EPS		32,686			$	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 the three months ended March 31, 2014 and 2013 (in thousands):
		Three Months Ended
		March 31,
		2014			2013
	Officers & Key Employees	$	581		$	573
	Directors	158			191
	Total Cost	739			764
	Capitalized	(70		)	(63		)
	Net Expense	$	669		$	701
	As of March 31, 2014, there was $5.0 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the restricted stock plans. That cost is expected to be recognized over a weighted average period of 2.1 years.
	The following table summarizes information regarding restricted stock award activity during the three months ended March 31, 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	67,874			11,610			$	50.13
	Cancelled/Forfeited	(7,618	)		—			$	50.24
	Vested	—			(19,617	)		$	52.19
	Nonvested Shares Outstanding, March 31, 2014	154,448			11,610			$	50.3
	Performance targets during the three-year vesting period were not attained for the January 2011 grant that had vested at December 31, 2013. As a result, no shares were awarded in 2014. During the three months ended March 31, 2013, SJI awarded 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 three months ended March 31, 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 these plans; 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	3 Months Ended
	Mar. 31, 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 months ended March 31, were (in thousands, except per share amounts):
		Three Months Ended
		March 31,
		2014			2013
	Loss Before Income Taxes:
	Sand Mining	$	(380	)	$	(72	)
	Fuel Oil	(102		)	(652		)
	Income Tax Benefits	169			253
	Loss from Discontinued Operations — Net	$	(313	)	$	(471	)
	Earnings Per Common Share from
	Discontinued Operations — Net:
	Basic and Diluted	$	(0.01	)	$	(0.01	)
	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.
	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 three months of 2014, the Company received net repayments from unconsolidated affiliates of $2.9 million. During the first three months of 2013, the Company made investments in, and provided net advances to, unconsolidated affiliates of $1.1 million, excluding the cash proceeds related to the sale of LVE as discussed above. As of March 31, 2014 and December 31, 2013, the outstanding balance on these Notes Receivable – Affiliate was $46.1 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 March 31, 2014, the Company had a net asset of approximately $79.5 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 March 31, 2014 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $125.6 million plus the guarantees discussed in Note 11.

COMMON_STOCK

COMMON STOCK	3 Months Ended
	Mar. 31, 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	95,662
	Stock-Based Compensation Plan	11,610
	Ending Balance, March 31	32,822,314
	The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $5.4 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 77,224 and 53,574 for the three months ended March 31, 2014 and 2013, respectively. 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 $5.2 million and $7.2 million of equity capital through the DRP during the three months ended March 31, 2014 and 2013, respectively.

FINANCIAL_INSTRUMENTS

FINANCIAL INSTRUMENTS	3 Months Ended
	Mar. 31, 2014
Financial Instruments, Owned, at Fair Value [Abstract]	'
Financial Instruments	'
	FINANCIAL INSTRUMENTS:
	RESTRICTED INVESTMENTS — In accordance with the terms of certain Marina and SJG loan agreements, unused proceeds are required to be escrowed pending approval of construction expenditures. As of March 31, 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 March 31, 2014 and December 31, 2013, the balances in these accounts totaled $34.3 million and $41.8 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at March 31, 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 $15.0 million as of both March 31, 2014 and December 31, 2013. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in 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 $1.3 million as of both March 31, 2014 and December 31, 2013.  The annual 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 March 31, 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 March 31, 2014, approximately $14.6 million, or 19.0%, of the current and noncurrent Derivatives – Energy Related Assets are with a single, investment-grade rated counterparty.
	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 March 31, 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. The impact on the condensed consolidated statements of income is not significant. As a result, the Company recorded $20.4 million and $20.7 million, net of amortization, within Finance Obligation on the condensed consolidated balance sheets at March 31, 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 March 31, 2014 and December 31, 2013, except as noted below.
	•	For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to 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 March 31, 2014 and December 31, 2013, were $759.3 million and $713.2 million, respectively.  The carrying amounts of SJI's long-term debt, including current maturities, as of March 31, 2014 and December 31, 2013, were $731.4 million and $701.4 million, respectively.

SEGMENTS_OF_BUSINESS

SEGMENTS OF BUSINESS	3 Months Ended
	Mar. 31, 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 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
		March 31,
		2014			2013
	Operating Revenues:
	Gas Utility Operations	$	210,545		$	174,098
	Energy Group:
	Wholesale Energy Operations	35,372			6,216
	Retail Gas and Other Operations	51,506			34,113
	Retail Electric Operations	40,393			30,729
	Subtotal Energy Group	127,271			71,058
	Energy Services:
	On-Site Energy Production	11,346			9,096
	Appliance Service Operations	2,654			3,308
	Subtotal Energy Services	14,000			12,404
	Corporate & Services	7,871			8,480
	Subtotal	359,687			266,040
	Intersegment Sales	(9,486		)	(10,409		)
	Total Operating Revenues	$	350,201		$	255,631
		Three Months Ended
		March 31,
		2014			2013
	Operating Income:
	Gas Utility Operations	$	63,440		$	57,795
	Energy Group:
	Wholesale Energy Operations	(1,655		)	(5,157		)
	Retail Gas and Other Operations	1,968			28
	Retail Electric Operations	(54		)	464
	Subtotal Energy Group	259			(4,665		)
	Energy Services:
	On-Site Energy Production	(1,260		)	(1,173		)
	Appliance Service Operations	(95		)	(14		)
	Subtotal Energy Services	(1,355		)	(1,187		)
	Corporate and Services	166			36
	Total Operating Income	$	62,510		$	51,979
	Depreciation and Amortization:
	Gas Utility Operations	$	12,676		$	11,024
	Energy Group:
	Wholesale Energy Operations	40			51
	Retail Gas and Other Operations	22			22
	Subtotal Energy Group	62			73
	Energy Services:
	On-Site Energy Production	5,775			3,012
	Appliance Service Operations	67			74
	Subtotal Energy Services	5,842			3,086
	Corporate and Services	219			225
	Total Depreciation and Amortization	$	18,799		$	14,408
	Interest Charges:
	Gas Utility Operations	$	4,342		$	2,961
	Energy Group:
	Wholesale Energy Operations	121			52
	Retail Gas and Other Operations	126			76
	Subtotal Energy Group	247			128
Energy Services:
On-Site Energy Production	2,128			1,403
Corporate and Services	1,850			1,508
Subtotal	8,567			6,000
Intersegment Borrowings	(1,483		)	(1,292		)
Total Interest Charges	$	7,084		$	4,708
	Three Months Ended
	March 31,
	2014			2013
Income Taxes:
Gas Utility Operations	$	22,527		$	20,771
Energy Group:
Wholesale Energy Operations	(553		)	(1,981		)
Retail Gas and Other Operations	936			272
Retail Electric Operations	(22		)	190
Subtotal Energy Group	361			(1,519		)
Energy Services:
On-Site Energy Production	(11,025		)	(11,564		)
Appliance Service Operations	(23		)	4
Subtotal Energy Services	(11,048		)	(11,560		)
Corporate and Services	29			80
Total Income Taxes	$	11,869		$	7,772
Property Additions:
Gas Utility Operations	$	32,531		$	37,042
Energy Group:
Wholesale Energy Operations	2			9
Retail Gas and Other Operations	168			2
Subtotal Energy Group	170			11
Energy Services:
On-Site Energy Production	9,149			2,577
Corporate and Services	778			738
Total Property Additions	$	42,628		$	40,368
	March 31, 2014			December 31, 2013
Identifiable Assets:
Gas Utility Operations	$	1,969,673		$	1,909,126
Energy Group:
Wholesale Energy Operations	325,400			331,182
Retail Gas and Other Operations	70,832			50,384
Retail Electric Operations	27,510			25,496
Subtotal Energy Group	423,742			407,062
Energy Services:
On-Site Energy Production	597,942			576,315
Appliance Service Operations	2,240			1,812
Subtotal Energy Services	600,182			578,127
Discontinued Operations	1,753			1,068
Corporate and Services	410,010			406,245
Intersegment Assets	(385,559		)	(376,773		)
Total Identifiable Assets	$	3,019,801		$	2,924,855

RATES_AND_REGULATORY_ACTIONS

RATES AND REGULATORY ACTIONS	3 Months Ended
	Mar. 31, 2014
Public Utilities, General Disclosures [Abstract]	'
RATES AND REGULATORY ACTIONS	'
	RATES AND REGULATORY ACTIONS:
	SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). In November 2013, SJG filed a base rate case with the BPU to increase its base rates to obtain a certain level of return on its capital investments. In March 2014, SJG filed an update to the original filing and expects the base rate case to be concluded during 2014.
	In January 2014, SJG credited the accounts of its periodic Basic Gas Supply Service (BGSS) customers with refunds totaling $11.2 million based on a projected over collection, at that time, due to lower gas costs.
	There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2013. See Note 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	3 Months Ended
	Mar. 31, 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):
		March 31, 2014		December 31, 2013
	Environmental Remediation Costs:
	Expended - Net	$	26,590	$	29,945
	Liability for Future Expenditures	119,604		119,492
	Deferred Asset Retirement Obligation Costs	31,347		31,142
	Deferred Pension and Other Postretirement Benefit Costs	59,284		59,284
	Deferred Gas Costs - Net	34,008		—
	Conservation Incentive Program Receivable	—		10,526
	Societal Benefit Costs Receivable	5,528		10,408
	Premium for Early Retirement of Debt	—		955
	Deferred Interest Rate Contracts	4,735		3,735
	Energy Efficiency Tracker	7,470		10,420
	Pipeline Supplier Service Charges	6,690		7,106
	Pipeline Integrity Cost	2,962		2,902
	AFUDC - Equity Related Deferrals	8,631		7,810
	Other Regulatory Assets	2,441		2,356
	Total Regulatory Assets	$	309,290	$	296,081
	DEFERRED GAS COSTS - NET - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. The change from a $19.1 million regulatory liability at December 31, 2013 to a $34.0 million regulatory asset at March 31, 2014 was due to the actual cost of the commodity incurred during the first quarter exceeding the gas costs recovered from the customers as a result of higher prices.
	CONSERVATION INCENTIVE PROGRAM (CIP) RECEIVABLE – The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. Actual usage per customer was greater than the established baseline during the first three months of 2014 resulting in a payable that is recorded in the table below as a regulatory liability. The change from a receivable to a related payable is primarily the result of colder weather experienced in the region during the first quarter of 2014.
	SOCIETAL BENEFIT COSTS RECEIVABLE - This regulatory asset primarily represents the deferred expenses under the New Jersey Clean Energy Program, which is a mechanism designed to recover costs associated with energy efficiency and renewable energy program. The decrease in the asset is due to colder weather experienced in the region during the first quarter of 2014 resulting in increased recoveries of the deferred expense.
	Regulatory Liabilities consisted of the following items (in thousands):
		March 31, 2014		December 31, 2013
	Excess Plant Removal Costs	$	39,647	$	40,029
	Deferred Revenues - Net	—		19,067
	Conservation Incentive Program Payable	6,193		—
	Other Regulatory Liabilities	2,318		1,853
	Total Regulatory Liabilities	$	48,158	$	60,949
	DEFERRED REVENUES – NET – Over/under collections of gas costs are monitored through SJG’s BGSS mechanism.  Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability.  Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. See "Deferred Gas Costs - Net" above.
	CONSERVATION INCENTIVE PROGRAM PAYABLE – The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. See "Conservation Incentive Program (CIP) Receivable" above.

PENSION_AND_OTHER_POSTRETIREME

PENSION AND OTHER POSTRETIREMENT BENEFITS	3 Months Ended
	Mar. 31, 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 months ended March 31, 2014 and 2013, net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):
		Pension Benefits
		Three Months Ended
		March 31,
		2014			2013
	Service Cost	$	1,285		$	1,378
	Interest Cost	2,695			2,332
	Expected Return on Plan Assets	(3,265		)	(2,989		)
	Amortizations:
	Prior Service Cost	43			63
	Actuarial Loss	1,426			2,171
	Net Periodic Benefit Cost	2,184			2,955
	Capitalized Benefit Costs	(854		)	(1,167		)
	Total Net Periodic Benefit Expense	$	1,330		$	1,788
		Other Postretirement Benefits
		Three Months Ended
		March 31,
		2014			2013
	Service Cost	$	250		$	311
	Interest Cost	740			700
	Expected Return on Plan Assets	(687		)	(588		)
	Amortizations:
	Prior Service Cost (Credits)	38			(71		)
	Actuarial Loss	243			459
	Net Periodic Benefit Cost	584			811
	Capitalized Benefit Costs	(209		)	(322		)
	Total Net Periodic Benefit Expense	$	375		$	489
	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 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	3 Months Ended
	Mar. 31, 2014
Line of Credit Facility [Abstract]	'
LINES OF CREDIT	'
	LINES OF CREDIT:
	Credit facilities and available liquidity as of March 31, 2014 were as follows (in thousands):
	Company	Total Facility		Usage		Available Liquidity		Expiration Date
	SJG:
	Commercial Paper Program/Revolving Credit Facility	$	200,000	$	47,700	$	152,300	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total SJG	210,000		47,700		162,300
	SJI:
	Revolving Credit Facility	400,000		293,800		106,200		February 2018 (A)
	Total SJI	400,000		293,800		106,200
	Total	$	610,000	$	341,500	$	268,500
	(A) Includes letters of credit outstanding in the amount of $17.2 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 1.06% and 1.02% at March 31, 2014 and 2013, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the three months ended March 31, 2014 and 2013 were $332.2 million and $317.3 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the three months ended March 31, 2014 and 2013 were $390.7 million and $369.5 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 March 31, 2014.
	SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million.  The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes.  SJG uses the commercial paper program in tandem with the $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 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 March 31, 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 March 31, 2014. As of December 31, 2013, LVE was dissolved and the Company incurred a $0.8 million charge to write-off the 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 in each 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 are unable to meet certain financial obligations as they become due. As of March 31, 2014, 50% of the currently outstanding debt is $9.4 million. As a result, the Company has recorded a liability of $0.5 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 March 31, 2014.
	In February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, in which Marina has a 50% equity interest, entered into a 20 year contract with a developer 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, ACR is providing full energy services to the complex. Marina and its joint venture partner have agreed to provide a $5.0 million letter of credit to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer. 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 to or on behalf of ACR.
	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 March 31, 2014, SJI had issued $6.4 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 March 31, 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 2014.
	STANDBY LETTERS OF CREDIT — As of March 31, 2014, SJI provided $17.2 million of standby letters of credit through SJI’s 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 $2.9 million and $3.0 million related to all claims in the aggregate as of March 31, 2014 and December 31, 2013, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.
	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	3 Months Ended
	Mar. 31, 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 March 31, 2014, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 30.3 MMdts (1 MMdts =ne million decatherms) of expected future purchases of natural gas, 20.4 MMdts of expected future sales of natural gas, 1.0 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 30.8 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 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 March 31, 2014 and December 31, 2013, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	March 31, 2014						December 31, 2013
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	58,123		$	89,892		$	56,327		$	77,993
	Derivatives – Energy Related – Non-Current	18,439			20,274			26,451			22,131
	Interest rate contracts:
	Derivatives - Other	—			7,890			—			6,676
	Total derivatives not designated as hedging instruments under GAAP	76,562			118,056			82,778			106,800
	Total Derivatives	$	76,562		$	118,056		$	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 March 31, 2014 and December 31, 2013, information related to these offsetting arrangements were as follows (in thousands):
	As of March 31, 2014
	Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet			Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
											Financial Instruments				Cash Collateral Posted
	Derivatives - Energy Related Assets	$	76,562		$	—		$	76,562		$	(39,526	)	(A)	$	—		$	37,036
	Derivatives - Energy Related Liabilities	$	(110,166	)	$	—		$	(110,166	)	$	39,526		(B)	$	17,275		$	(53,365	)
	Derivatives - Other	$	(7,890	)	$	—		$	(7,890	)	$	—			$	—		$	(7,890	)
	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 March 31, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at March 31, 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 months ended March 31, 2014 and 2013 are as follows (in thousands):
		Three Months Ended
		March 31,
	Derivatives in Cash Flow Hedging Relationships under GAAP	2014			2013
	Interest Rate Contracts:
	Losses recognized in AOCL on effective portion	$	—		$	—
	Losses reclassified from AOCL into income (a)	$	(112	)	$	(112	)
	Gains (losses) recognized in income on ineffective portion (a)	$	—		$	—
	(a) Included in Interest Charges
		Three Months Ended
		March 31,
	Derivatives Not Designated as Hedging Instruments under GAAP	2014			2013
	Losses on energy related commodity contracts (a)	$	(28,601	)	$	(7,049	)
	(Losses) gains on interest rate contracts (b)	(214		)	525
	Total	$	(28,815	)	$	(6,524	)
	(a)  Included in Operating Revenues - Non Utility
	(b)  Included in Interest Charges
	Net realized gains associated with SJG's energy-related financial commodity contracts of $2.4 million and losses of $1.5 million for the three months ended March 31, 2014 and 2013, respectively, are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy related financial commodity contracts are deferred in Regulatory Assets or Liabilities and there is no impact to earnings.
	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 March 31, 2014, is $38.4 million.   If the credit-risk-related contingent features underlying these agreements were triggered on March 31, 2014, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $28.3 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	3 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	'
	FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES:
	GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques.  The levels of the hierarchy are described below:
	•	Level 1:  Observable inputs such as quoted prices in active markets for identical assets or liabilities.
	•	Level 2:  Inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly; these include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.
	•	Level 3:  Unobservable inputs that reflect the reporting entity’s own assumptions.
	Assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of financial assets and financial liabilities and their placement within the fair value hierarchy.
	For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands):
	As of March 31, 2014	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,829			$	8,829			$	—	$	—
	Derivatives – Energy Related Assets (B)	76,562				7,109				28,935		40,518
		$	85,391			$	15,938			$	28,935	$	40,518
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	110,166			$	5,732			$	58,945	$	45,489
	Derivatives – Other (C)	7,890				—				7,890		—
		$	118,056			$	5,732			$	66,835	$	45,489
	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 and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy.
	(B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. 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 March 31, 2014		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets	Liabilities
	Forward Contract - Natural Gas	$31,078	$38,549	Discounted Cash Flow	Forward price (per dt)	$(2.01) - $4.70 [$(0.78)]
	Forward Contract - Electric	$9,440	$6,940	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [55.03%]
					Fixed electric load profile (off-peak)	0.00% - 91.94% [44.97%]
	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 months ended March 31, 2014 and 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
		Three Months Ended
		31-Mar-14
	Balance at beginning of period	$	8,095
	Other changes in fair value from continuing and new contracts, net	(12,124		)
	Settlements	(942		)
	Balance at end of period	$	(4,971	)
		Three Months Ended
		31-Mar-13
	Balance at beginning of period	2,762
	Other changes in fair value from continuing and new contracts, net	(701		)
	Settlements	(434		)
	Balance at end of period	$	1,627
	Total losses for 2014 included in earnings that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of March 31, 2014, is $12.1 million.  These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

LONGTERM_DEBT

LONG-TERM DEBT	3 Months Ended
	Mar. 31, 2014
Long-term Debt, Unclassified [Abstract]	'
LONG-TERM DEBT	'
	LONG-TERM DEBT:
	In January 2014, SJG issued $30.0 million aggregate principal amount of 4.23% Medium Term Notes due January 2030.
	The Company did not issue any other long-term debt during the three months ended March 31, 2014.

ACCUMULATED_OTHER_COMPREHENSIV

ACCUMULATED OTHER COMPREHENSIVE LOSS	3 Months Ended
	Mar. 31, 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 months ended March 31, 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 January 1, 2014 (a)	$	(18,503	)	$	(2,697	)	$	397	$	43		$	(20,760	)
	Other comprehensive income before reclassifications	—			—			62		—			62
	Amounts reclassified from AOCL (b)	—			66			—		(18		)	48
	Net current period other comprehensive income (loss)	—			66			62		(18		)	110
	Balance at March 31, 2014 (a)	$	(18,503	)	$	(2,631	)	$	459	$	25		$	(20,650	)
	(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 months ended March 31, 2014:
		Amounts Reclassified from AOCL (in thousands)			Affected Line Item in the Condensed Consolidated Statements of Income
		Three Months Ended
		31-Mar-14
	Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	112		Interest Charges
	Income Taxes	(46		)	Income Taxes (a)
		$	66
	Loss of Affiliated Companies	$	(31	)	Equity in Loss of Affiliated Companies
	Income Taxes	13			Income Taxes (a)
		$	(18	)
	Losses from reclassifications for the period net of tax	$	48

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
	Mar. 31, 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. No impairment was recorded during the three months ended March 31, 2014 or 2013. As of both March 31, 2014 and December 31, 2013, $8.9 million 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	'
	TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of March 31, 2014 and December 31, 2013, SJI held 129,929 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	'
	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.
FAIR VALUE	'
	(A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy.
	(B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. 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)	3 Months Ended
	Mar. 31, 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 March 31, 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		18,640			$	51.23		22.5	%	0.43	%
		Jan. 2012 - EPS		18,640			$	56.93		N/A		N/A
		Jan. 2013 - TSR		25,898			$	44.38		21.1	%	0.4	%
		Jan. 2013 - EPS		25,898			$	51.18		N/A		N/A
		Jan. 2014 - TSR		32,686			$	44.32		20	%	0.8	%
		Jan. 2014 - EPS		32,686			$	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 the three months ended March 31, 2014 and 2013 (in thousands):
		Three Months Ended
		March 31,
		2014			2013
	Officers & Key Employees	$	581		$	573
	Directors	158			191
	Total Cost	739			764
	Capitalized	(70		)	(63		)
	Net Expense	$	669		$	701
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 three months ended March 31, 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	67,874			11,610			$	50.13
	Cancelled/Forfeited	(7,618	)		—			$	50.24
	Vested	—			(19,617	)		$	52.19
	Nonvested Shares Outstanding, March 31, 2014	154,448			11,610			$	50.3

DISCONTINUED_OPERATIONS_AND_AF1

DISCONTINUED OPERATIONS AND AFFILIATIONS (Tables)	3 Months Ended
	Mar. 31, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
Summarized operating results of the discontinued operations	'
	Summarized operating results of the discontinued operations for the three months ended March 31, were (in thousands, except per share amounts):
		Three Months Ended
		March 31,
		2014			2013
	Loss Before Income Taxes:
	Sand Mining	$	(380	)	$	(72	)
	Fuel Oil	(102		)	(652		)
	Income Tax Benefits	169			253
	Loss from Discontinued Operations — Net	$	(313	)	$	(471	)
	Earnings Per Common Share from
	Discontinued Operations — Net:
	Basic and Diluted	$	(0.01	)	$	(0.01	)

COMMON_STOCK_Tables

COMMON STOCK (Tables)	3 Months Ended
	Mar. 31, 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	95,662
	Stock-Based Compensation Plan	11,610
	Ending Balance, March 31	32,822,314

SEGMENTS_OF_BUSINESS_Tables

SEGMENTS OF BUSINESS (Tables)	3 Months Ended
	Mar. 31, 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
		March 31,
		2014			2013
	Operating Revenues:
	Gas Utility Operations	$	210,545		$	174,098
	Energy Group:
	Wholesale Energy Operations	35,372			6,216
	Retail Gas and Other Operations	51,506			34,113
	Retail Electric Operations	40,393			30,729
	Subtotal Energy Group	127,271			71,058
	Energy Services:
	On-Site Energy Production	11,346			9,096
	Appliance Service Operations	2,654			3,308
	Subtotal Energy Services	14,000			12,404
	Corporate & Services	7,871			8,480
	Subtotal	359,687			266,040
	Intersegment Sales	(9,486		)	(10,409		)
	Total Operating Revenues	$	350,201		$	255,631
		Three Months Ended
		March 31,
		2014			2013
	Operating Income:
	Gas Utility Operations	$	63,440		$	57,795
	Energy Group:
	Wholesale Energy Operations	(1,655		)	(5,157		)
	Retail Gas and Other Operations	1,968			28
	Retail Electric Operations	(54		)	464
	Subtotal Energy Group	259			(4,665		)
	Energy Services:
	On-Site Energy Production	(1,260		)	(1,173		)
	Appliance Service Operations	(95		)	(14		)
	Subtotal Energy Services	(1,355		)	(1,187		)
	Corporate and Services	166			36
	Total Operating Income	$	62,510		$	51,979
	Depreciation and Amortization:
	Gas Utility Operations	$	12,676		$	11,024
	Energy Group:
	Wholesale Energy Operations	40			51
	Retail Gas and Other Operations	22			22
	Subtotal Energy Group	62			73
	Energy Services:
	On-Site Energy Production	5,775			3,012
	Appliance Service Operations	67			74
	Subtotal Energy Services	5,842			3,086
	Corporate and Services	219			225
	Total Depreciation and Amortization	$	18,799		$	14,408
	Interest Charges:
	Gas Utility Operations	$	4,342		$	2,961
	Energy Group:
	Wholesale Energy Operations	121			52
	Retail Gas and Other Operations	126			76
	Subtotal Energy Group	247			128
	Energy Services:
	On-Site Energy Production	2,128			1,403
	Corporate and Services	1,850			1,508
	Subtotal	8,567			6,000
	Intersegment Borrowings	(1,483		)	(1,292		)
	Total Interest Charges	$	7,084		$	4,708
		Three Months Ended
		March 31,
		2014			2013
	Income Taxes:
Gas Utility Operations	$	22,527		$	20,771
Energy Group:
Wholesale Energy Operations	(553		)	(1,981		)
Retail Gas and Other Operations	936			272
Retail Electric Operations	(22		)	190
Subtotal Energy Group	361			(1,519		)
Energy Services:
On-Site Energy Production	(11,025		)	(11,564		)
Appliance Service Operations	(23		)	4
Subtotal Energy Services	(11,048		)	(11,560		)
Corporate and Services	29			80
Total Income Taxes	$	11,869		$	7,772
Property Additions:
Gas Utility Operations	$	32,531		$	37,042
Energy Group:
Wholesale Energy Operations	2			9
Retail Gas and Other Operations	168			2
Subtotal Energy Group	170			11
Energy Services:
On-Site Energy Production	9,149			2,577
Corporate and Services	778			738
Total Property Additions	$	42,628		$	40,368
	March 31, 2014			December 31, 2013
Identifiable Assets:
Gas Utility Operations	$	1,969,673		$	1,909,126
Energy Group:
Wholesale Energy Operations	325,400			331,182
Retail Gas and Other Operations	70,832			50,384
Retail Electric Operations	27,510			25,496
Subtotal Energy Group	423,742			407,062
Energy Services:
On-Site Energy Production	597,942			576,315
Appliance Service Operations	2,240			1,812
Subtotal Energy Services	600,182			578,127
Discontinued Operations	1,753			1,068
Corporate and Services	410,010			406,245
Intersegment Assets	(385,559		)	(376,773		)
Total Identifiable Assets	$	3,019,801		$	2,924,855

REGULATORY_ASSETS_REGULATORY_L1

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

PENSION_AND_OTHER_POSTRETIREME1

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	3 Months Ended
	Mar. 31, 2014
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]	'
Schedule of defined benefit plans disclosures	'
	For the three months ended March 31, 2014 and 2013, net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):
		Pension Benefits
		Three Months Ended
		March 31,
		2014			2013
	Service Cost	$	1,285		$	1,378
	Interest Cost	2,695			2,332
	Expected Return on Plan Assets	(3,265		)	(2,989		)
	Amortizations:
	Prior Service Cost	43			63
	Actuarial Loss	1,426			2,171
	Net Periodic Benefit Cost	2,184			2,955
	Capitalized Benefit Costs	(854		)	(1,167		)
	Total Net Periodic Benefit Expense	$	1,330		$	1,788
		Other Postretirement Benefits
		Three Months Ended
		March 31,
		2014			2013
	Service Cost	$	250		$	311
	Interest Cost	740			700
	Expected Return on Plan Assets	(687		)	(588		)
	Amortizations:
	Prior Service Cost (Credits)	38			(71		)
	Actuarial Loss	243			459
	Net Periodic Benefit Cost	584			811
	Capitalized Benefit Costs	(209		)	(322		)
	Total Net Periodic Benefit Expense	$	375		$	489

LINES_OF_CREDIT_Tables

LINES OF CREDIT (Tables)	3 Months Ended
	Mar. 31, 2014
Line of Credit Facility [Abstract]	'
Schedule of lines of credit	'
	Credit facilities and available liquidity as of March 31, 2014 were as follows (in thousands):
	Company	Total Facility		Usage		Available Liquidity		Expiration Date
	SJG:
	Commercial Paper Program/Revolving Credit Facility	$	200,000	$	47,700	$	152,300	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-14
	Total SJG	210,000		47,700		162,300
	SJI:
	Revolving Credit Facility	400,000		293,800		106,200		February 2018 (A)
	Total SJI	400,000		293,800		106,200
	Total	$	610,000	$	341,500	$	268,500
	(A) Includes letters of credit outstanding in the amount of $17.2 million.

DERIVATIVE_INSTRUMENTS_Tables

DERIVATIVE INSTRUMENTS (Tables)	3 Months Ended
	Mar. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Fair value of derivative instruments	'
	The fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of March 31, 2014 and December 31, 2013, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	March 31, 2014						December 31, 2013
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	58,123		$	89,892		$	56,327		$	77,993
	Derivatives – Energy Related – Non-Current	18,439			20,274			26,451			22,131
	Interest rate contracts:
	Derivatives - Other	—			7,890			—			6,676
	Total derivatives not designated as hedging instruments under GAAP	76,562			118,056			82,778			106,800
	Total Derivatives	$	76,562		$	118,056		$	82,778		$	106,800
Offsetting assets and liabilities	'
	As of March 31, 2014 and December 31, 2013, information related to these offsetting arrangements were as follows (in thousands):
	As of March 31, 2014
	Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet			Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
											Financial Instruments				Cash Collateral Posted
	Derivatives - Energy Related Assets	$	76,562		$	—		$	76,562		$	(39,526	)	(A)	$	—		$	37,036
	Derivatives - Energy Related Liabilities	$	(110,166	)	$	—		$	(110,166	)	$	39,526		(B)	$	17,275		$	(53,365	)
	Derivatives - Other	$	(7,890	)	$	—		$	(7,890	)	$	—			$	—		$	(7,890	)
	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 March 31, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at March 31, 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 months ended March 31, 2014 and 2013 are as follows (in thousands):
		Three Months Ended
		March 31,
	Derivatives in Cash Flow Hedging Relationships under GAAP	2014			2013
	Interest Rate Contracts:
	Losses recognized in AOCL on effective portion	$	—		$	—
	Losses reclassified from AOCL into income (a)	$	(112	)	$	(112	)
	Gains (losses) recognized in income on ineffective portion (a)	$	—		$	—
	(a) Included in Interest Charges
		Three Months Ended
		March 31,
	Derivatives Not Designated as Hedging Instruments under GAAP	2014			2013
	Losses on energy related commodity contracts (a)	$	(28,601	)	$	(7,049	)
	(Losses) gains on interest rate contracts (b)	(214		)	525
	Total	$	(28,815	)	$	(6,524	)
	(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)	3 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
Fair value of assets and liabilities	'
	For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands):
	As of March 31, 2014	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,829			$	8,829			$	—	$	—
	Derivatives – Energy Related Assets (B)	76,562				7,109				28,935		40,518
		$	85,391			$	15,938			$	28,935	$	40,518
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	110,166			$	5,732			$	58,945	$	45,489
	Derivatives – Other (C)	7,890				—				7,890		—
		$	118,056			$	5,732			$	66,835	$	45,489
	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 and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy.
	(B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. 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 March 31, 2014		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets	Liabilities
	Forward Contract - Natural Gas	$31,078	$38,549	Discounted Cash Flow	Forward price (per dt)	$(2.01) - $4.70 [$(0.78)]
	Forward Contract - Electric	$9,440	$6,940	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [55.03%]
					Fixed electric load profile (off-peak)	0.00% - 91.94% [44.97%]
	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 months ended March 31, 2014 and 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
		Three Months Ended
		31-Mar-14
	Balance at beginning of period	$	8,095
	Other changes in fair value from continuing and new contracts, net	(12,124		)
	Settlements	(942		)
	Balance at end of period	$	(4,971	)
		Three Months Ended
		31-Mar-13
	Balance at beginning of period	2,762
	Other changes in fair value from continuing and new contracts, net	(701		)
	Settlements	(434		)
	Balance at end of period	$	1,627

ACCUMULATED_OTHER_COMPREHENSIV1

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	3 Months Ended
	Mar. 31, 2014
Equity [Abstract]	'
Schedule of changes in accumulated other comprehensive loss (AOCL)	'
	The following tables summarize the changes in accumulated other comprehensive loss (AOCL) for the three months ended March 31, 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 January 1, 2014 (a)	$	(18,503	)	$	(2,697	)	$	397	$	43		$	(20,760	)
	Other comprehensive income before reclassifications	—			—			62		—			62
	Amounts reclassified from AOCL (b)	—			66			—		(18		)	48
	Net current period other comprehensive income (loss)	—			66			62		(18		)	110
	Balance at March 31, 2014 (a)	$	(18,503	)	$	(2,631	)	$	459	$	25		$	(20,650	)
	(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 months ended March 31, 2014:
		Amounts Reclassified from AOCL (in thousands)			Affected Line Item in the Condensed Consolidated Statements of Income
		Three Months Ended
		31-Mar-14
	Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	112		Interest Charges
	Income Taxes	(46		)	Income Taxes (a)
		$	66
	Loss of Affiliated Companies	$	(31	)	Equity in Loss of Affiliated Companies
	Income Taxes	13			Income Taxes (a)
		$	(18	)
	Losses from reclassifications for the period net of tax	$	48

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Accounting Policies [Abstract]	'	'	'
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales	$400,000	$400,000	'
Impairment charges	0	0	'
Amount of costs related to interests in proved and unproved properties in Pennsylvania, net of amortization	$8,900,000	'	$8,900,000
Shares of treasury stock held (in shares)	129,929	'	148,890

STOCKBASED_COMPENSATION_PLAN_D

STOCK-BASED COMPENSATION PLAN (Details) (USD $)	3 Months Ended		12 Months Ended
	Mar. 31, 2014	Mar. 31, 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	'	'
Number of options granted	0	0	'
Fair value per share (in dollars per share)	$50.30	'	'
Cost	$739,000	$764,000	'
Capitalized	-70,000	-63,000	'
Net expense	669,000	701,000	'
Unrecognized compensation cost of awards granted under the plan	5,000,000	'	'
Weighted average period over which unrecognized compensation cost is to be recognized (in years)	'2 years 1 month 6 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)	$50.13	'	'
Weighted average fair value nonvested shares-cancelled/forfeited during the period (in dollars per share)	$50.24	'	'
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)	$50.30	'	'
Officers and Key Employees [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Number of shares granted	67,874	56,464	'
Vesting period of shares (in years)	'3 years	'	'
The range of the actual amount of shares that ultimately vest of the original share units granted (in hundredths)	'0% to 150%	'	'
Shares outstanding (in shares)	154,448	'	'
Cost	581,000	573,000	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'
Nonvested shares outstanding, beginning balance (in shares)	94,192	'	'
Granted (in shares)	67,874	56,464	'
Cancelled/Forfeited (in shares)	-7,618	'	'
Vested (in shares)	0	'	'
Nonvested shares outstanding, ending balance (in shares)	154,448	'	'
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 [Member] | Grant Date January 2012 - TSR [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Shares outstanding (in shares)	18,640	'	'
Fair value per share (in dollars per share)	$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)	18,640	'	'
Additional disclosures [Abstract]	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$51.23	'	'
Officers and Key Employees [Member] | Grant Date January 2012 - EPS [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Shares outstanding (in shares)	18,640	'	'
Fair value per share (in dollars per share)	$56.93	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'
Nonvested shares outstanding, ending balance (in shares)	18,640	'	'
Additional disclosures [Abstract]	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$56.93	'	'
Officers and Key Employees [Member] | Grant Date January 2013 - TSR [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Shares outstanding (in shares)	25,898	'	'
Fair value per share (in dollars per share)	$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)	25,898	'	'
Additional disclosures [Abstract]	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$44.38	'	'
Officers and Key Employees [Member] | Grant Date January 2013 - EPS [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Shares outstanding (in shares)	25,898	'	'
Fair value per share (in dollars per share)	$51.18	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'
Nonvested shares outstanding, ending balance (in shares)	25,898	'	'
Additional disclosures [Abstract]	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$51.18	'	'
Officers and Key Employees [Member] | Grant Date January 2014, TSR [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Shares outstanding (in shares)	32,686	'	'
Fair value per share (in dollars per share)	$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)	32,686	'	'
Additional disclosures [Abstract]	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$44.32	'	'
Officers and Key Employees [Member] | Grant Date January 2014, EPS [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Shares outstanding (in shares)	32,686	'	'
Fair value per share (in dollars per share)	$54.44	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'
Nonvested shares outstanding, ending balance (in shares)	32,686	'	'
Additional disclosures [Abstract]	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$54.44	'	'
Directors [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Number of shares granted	11,610	12,285	'
Vesting period of shares (in years)	'3 years	'	'
Shares Vested, Directors (in hundredths)	100.00%	'	'
Shares outstanding (in shares)	11,610	'	'
Cost	158,000	191,000	'
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	'	'
Additional disclosures [Abstract]	'	'	'
Market value of shares awarded	$600,000	$600,000	'
Directors [Member] | Grant Date January 2014 [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Shares outstanding (in shares)	11,610	'	'
Fair value per share (in dollars per share)	$54.51	'	'
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]	'	'	'
Nonvested shares outstanding, ending balance (in shares)	11,610	'	'
Additional disclosures [Abstract]	'	'	'
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$54.51	'	'
Minimum [Member] | Officers and Key Employees [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Percentage of actual amount of shares that ultimately vest of original share units granted	0.00%	'	'
Maximum [Member] | Officers and Key Employees [Member]	'	'	'
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]	'	'	'
Percentage of actual amount of shares that ultimately vest of original share units granted	150.00%	'	'
Stock Appreciation Rights (SARs) [Member]	'	'	'
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
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Loss before Income Taxes: [Abstract]	'	'
Income Tax Benefits	$169	$253
Loss from Discontinued Operations b Net	-313	-471
Earnings per common share from discontinued operations, net [Abstract]	'	'
Basic and Diluted (in dollars per share)	($0.01)	($0.01)
Sand Mining [Member]	'	'
Loss before Income Taxes: [Abstract]	'	'
Loss Before Income Taxes	-380	-72
Fuel Oil [Member]	'	'
Loss before Income Taxes: [Abstract]	'	'
Loss Before Income Taxes	($102)	($652)

DISCONTINUED_OPERATIONS_AND_AF3

DISCONTINUED OPERATIONS AND AFFILIATIONS 2 (Details) (USD $)	3 Months Ended							12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2010	Mar. 31, 2014	Apr. 30, 2007	Dec. 31, 2013
				Energenic US LLC [Member]	Energenic US LLC [Member]	Potato Creek, LLC (Potato Creek) [Member]	LVE Energy Partners, LLC (LVE) [Member]	LVE Energy Partners, LLC (LVE) [Member]
					Marina Energy LLC [Member]		Marina Energy LLC [Member]	LVE Energy Partners [Member]
								Marina Energy LLC [Member]
Affiliations [Abstract]	'	'	'	'	'	'	'	'
Equity interest (in hundredths)	'	'	'	50.00%	50.00%	30.00%	50.00%	'
Proceeds from sale of joint venture	'	'	'	'	'	'	'	$57.90
Investments in unconsolidated affiliates	2.9	1.1	'	'	'	'	'	'
Notes Receivable - affiliate	46.1	'	48.8	'	'	'	'	'
Interest accrual on secured notes receivable (in hundredths)	7.50%	'	'	'	'	'	'	'
Repayment period, latest date	'2025	'	'	'	'	'	'	'
Net asset - included in investment in affiliates and other noncurrent liabilities	79.5	'	'	'	'	'	'	'
Combined equity contributions and the notes receivable - affiliate	$125.60	'	'	'	'	'	'	'

COMMON_STOCK_Details

COMMON STOCK (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Common Stock [Roll Forward]	'	'
Beginning balance (in shares)	32,715,042	'
New issues during period [Abstract]	'	'
Dividend reinvestment plan (in shares)	95,662	'
Stock-based compensation plan (in shares)	11,610	'
Ending balance (in shares)	32,822,314	'
Par value of common stock (in dollars per share)	$1.25	'
Net excess over par value recorded in premium on common stock	$5,400,000	'
Incremental shares included in diluted earnings per share (in shares)	77,224	53,574
Proceeds from sale of common stock	$5,157,000	$7,244,000

FINANCIAL_INSTRUMENTS_Details

FINANCIAL INSTRUMENTS (Details) (USD $)	Mar. 31, 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	34.3	41.8
South Jersey Gas Company [Member] | Financing Receivable [Member]	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Long-term receivables, net of unamortized discount	15	0
Imputed interest on long term receivables	$1.30	$1.30

FINANCIAL_INSTRUMENTS_2_Detail

FINANCIAL INSTRUMENTS 2 (Details) (Derivatives Energy Related Assets [Member], Supplier Concentration Risk [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014
Derivatives Energy Related Assets [Member] | Supplier Concentration Risk [Member]	'
Concentration Risk [Line Items]	'
Amount of derivatives - energy related assets with single retail counterparty	$14.60
Percentage of derivatives - energy related assets with a single retail counterparty (in hundredths)	19.00%

FINANCIAL_INSTRUMENTS_3_Detail

FINANCIAL INSTRUMENTS 3 (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Dec. 31, 2010
			Energenic US LLC [Member]	Marina Energy LLC [Member]	Marina Energy LLC [Member]	Marina Energy LLC [Member]
				Energenic US LLC [Member]	Energenic US LLC [Member]	Energenic US LLC [Member]
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'	'
Equity interest of Marina in Energenic	'	'	50.00%	'	'	50.00%
Other construction costs	'	'	'	$23,700,000	$23,700,000	'
Finance obligation to ACB Energy Partners LLC	20,420,000	20,656,000	'	20,400,000	20,700,000	'
Estimated fair value of long-term debt	759,300,000	713,200,000	'	'	'	'
Carrying amount of long-term debt	$731,400,000	$701,400,000	'	'	'	'

SEGMENTS_OF_BUSINESS_Details

SEGMENTS OF BUSINESS (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	$350,201	$255,631	'
Operating income (loss)	62,510	51,979	'
Depreciation and amortization	18,799	14,408	'
Interest charges	7,084	4,708	'
Income taxes	11,869	7,772	'
Property additions	42,628	40,368	'
Identifiable assets	3,019,801	'	2,924,855
Operating Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	359,687	266,040	'
Interest charges	8,567	6,000	'
Operating Segments [Member] | Gas Utility Operations [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	210,545	174,098	'
Operating income (loss)	63,440	57,795	'
Depreciation and amortization	12,676	11,024	'
Interest charges	4,342	2,961	'
Income taxes	22,527	20,771	'
Property additions	32,531	37,042	'
Identifiable assets	1,969,673	'	1,909,126
Operating Segments [Member] | Energy Group [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	127,271	71,058	'
Operating income (loss)	259	-4,665	'
Depreciation and amortization	62	73	'
Interest charges	247	128	'
Income taxes	361	-1,519	'
Property additions	170	11	'
Identifiable assets	423,742	'	407,062
Operating Segments [Member] | Energy Group [Member] | Wholesale Energy Operations [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	35,372	6,216	'
Operating income (loss)	-1,655	-5,157	'
Depreciation and amortization	40	51	'
Interest charges	121	52	'
Income taxes	-553	-1,981	'
Property additions	2	9	'
Identifiable assets	325,400	'	331,182
Operating Segments [Member] | Energy Group [Member] | Retail Gas and Other Operations [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	51,506	34,113	'
Operating income (loss)	1,968	28	'
Depreciation and amortization	22	22	'
Interest charges	126	76	'
Income taxes	936	272	'
Property additions	168	2	'
Identifiable assets	70,832	'	50,384
Operating Segments [Member] | Energy Group [Member] | Retail Electric Operations [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	40,393	30,729	'
Operating income (loss)	-54	464	'
Income taxes	-22	190	'
Identifiable assets	27,510	'	25,496
Operating Segments [Member] | Energy Services [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	14,000	12,404	'
Operating income (loss)	-1,355	-1,187	'
Depreciation and amortization	5,842	3,086	'
Income taxes	-11,048	-11,560	'
Identifiable assets	600,182	'	578,127
Operating Segments [Member] | Energy Services [Member] | On-site Energy Production [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	11,346	9,096	'
Operating income (loss)	-1,260	-1,173	'
Depreciation and amortization	5,775	3,012	'
Interest charges	2,128	1,403	'
Income taxes	-11,025	-11,564	'
Property additions	9,149	2,577	'
Identifiable assets	597,942	'	576,315
Operating Segments [Member] | Energy Services [Member] | Appliance Service Operations [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	2,654	3,308	'
Operating income (loss)	-95	-14	'
Depreciation and amortization	67	74	'
Income taxes	-23	4	'
Identifiable assets	2,240	'	1,812
Operating Segments [Member] | Corporate and Services [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	7,871	8,480	'
Operating income (loss)	166	36	'
Depreciation and amortization	219	225	'
Interest charges	1,850	1,508	'
Income taxes	29	80	'
Property additions	778	738	'
Identifiable assets	410,010	'	406,245
Discontinued Operations [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Identifiable assets	1,753	'	1,068
Intersegment Elimination [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Operating revenues	-9,486	-10,409	'
Interest charges	-1,483	-1,292	'
Identifiable assets	($385,559)	'	($376,773)

RATES_AND_REGULATORY_ACTIONS_D

RATES AND REGULATORY ACTIONS (Details) (Basic Gas Supply Service [Member], USD $)	1 Months Ended
In Millions, unless otherwise specified	Jan. 31, 2014
Basic Gas Supply Service [Member]	'
Schedule of Capitalization [Line Items]	'
BGSS refunds made to customers	$11.20

REGULATORY_ASSETS_REGULATORY_L2

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

REGULATORY_ASSETS_REGULATORY_L3

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

PENSION_AND_OTHER_POSTRETIREME2

PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) (USD $)	1 Months Ended	3 Months Ended
	Jan. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
Pension Benefits [Member]	'	'	'
Net periodic benefit cost [Abstract]	'	'	'
Service cost	'	$1,285,000	$1,378,000
Interest cost	'	2,695,000	2,332,000
Expected return on plan assets	'	-3,265,000	-2,989,000
Amortizations [Abstract]	'	'	'
Prior service cost (credits)	'	43,000	63,000
Actuarial loss	'	1,426,000	2,171,000
Net Periodic Benefit Cost	'	2,184,000	2,955,000
Capitalized benefit costs	'	-854,000	-1,167,000
Total net periodic benefit expense	'	1,330,000	1,788,000
Contributions	12,700,000	'	'
Other Postretirement Benefits [Member]	'	'	'
Net periodic benefit cost [Abstract]	'	'	'
Service cost	'	250,000	311,000
Interest cost	'	740,000	700,000
Expected return on plan assets	'	-687,000	-588,000
Amortizations [Abstract]	'	'	'
Prior service cost (credits)	'	38,000	-71,000
Actuarial loss	'	243,000	459,000
Net Periodic Benefit Cost	'	584,000	811,000
Capitalized benefit costs	'	-209,000	-322,000
Total net periodic benefit expense	'	375,000	489,000
Defined benefit plan regulatory obligation to contribute to the plan during the period	'	3,600,000	'
Supplemental Employee Retirement Plans, Defined Benefit [Member]	'	'	'
Amortizations [Abstract]	'	'	'
Estimated future contributions	'	$1,300,000	'

LINES_OF_CREDIT_Details

LINES OF CREDIT (Details) (USD $)	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Line of Credit Facility [Line Items]	'		'
Total facility	$610,000,000		'
Usage	341,500,000		'
Available liquidity	268,500,000		'
Letters of credit outstanding	17,200,000		'
Weighted average borrowing cost	1.06%		1.02%
Average borrowings outstanding during the period	332,200,000		317,300,000
Maximum amounts outstanding during the period	390,700,000		369,500,000
Financial covenant, ratio of indebtedness to consolidated total capitalization	'0.65 to 1		'
Minimum [Member]	'		'
Line of Credit Facility [Line Items]	'		'
Financial covenant, ratio of indebtedness to consolidated total capitalization minimum	0.65		'
SJG Commercial Paper Program [Member]	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	200,000,000		'
Fixed maturities of notes, at maximum number of days (in days)	'270 days		'
South Jersey Gas Company [Member]	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	210,000,000		'
Usage	47,700,000		'
Available liquidity	162,300,000		'
South Jersey Gas Company [Member] | Revolving Credit Facility [Member]	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	200,000,000		'
Usage	47,700,000		'
Available liquidity	152,300,000		'
Expiration date	'May 2018		'
South Jersey Gas Company [Member] | Uncommitted Bank Lines [Member]	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	10,000,000		'
Usage	0		'
Available liquidity	10,000,000		'
Expiration date	'August 2014		'
South Jersey Industries Inc [Member]	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	400,000,000		'
Usage	293,800,000		'
Available liquidity	106,200,000		'
South Jersey Industries Inc [Member] | Revolving Credit Facility [Member]	'		'
Line of Credit Facility [Line Items]	'		'
Total facility	400,000,000	[1]	'
Usage	293,800,000	[1]	'
Available liquidity	$106,200,000	[1]	'
Expiration date	'February 2018 (A)	[1]	'
[1]	Includes letters of credit outstanding in the amount of $17.2 million.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Details) (USD $)

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Feb. 28, 2011

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

31-May-12

31-May-12

Mar. 31, 2014

Apr. 30, 2007

Dec. 31, 2013

unions

Letter of Credit, Developer [Member]

Standby Letter of Credit [Member]

Letter of Credit, Separate Facility [Member]

ACR Energy Partners LLC [Member]

ACR Energy Partners LLC [Member]

LVE Energy Partners [Member]

LVE Energy Partners [Member]

Energenic [Member]

Energenic [Member]

Energenic [Member]

Parental Guarantee [Member]

Marina Energy LLC [Member]

Marina Energy LLC [Member]

sites

UMM Energy Partners, LLC [Member]

UMM Energy Partners, LLC [Member]

LVE Energy Partners, LLC (LVE) [Member]

LVE Energy Partners, LLC (LVE) [Member]

Maximum [Member]

LVE Energy Partners [Member]

Guarantees [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability recorded related to guarantees

$700,000

'

'

'

'

'

'

'

$800,000

$500,000

'

'

'

'

'

Equity interest (in hundredths)

'

'

'

'

'

'

50.00%

'

'

50.00%

'

'

'

50.00%

'

Contract with a resort developer

'

'

'

'

'

'20 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

6,536,000

8,908,000

'

'

'

'

'

9,400,000

'

'

'

'

'

'

'

Letter of credit provided

610,000,000

'

5,000,000

17,200,000

87,600,000

'

'

'

'

'

'

'

'

'

'

Contract term

'

'

'

'

'

'

'

'

'

'

'30 years

'

'

'

'

Annual obligations under the agreement

'

'

'

'

'

'

'

'

'

'

'

2,200,000

'

'

'

Guaranteed amount

'

'

'

'

'

'

'

'

'

'

'

'

6,400,000

'

'

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

$2,900,000

$3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental remediation costs [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

DERIVATIVE_INSTRUMENTS_Details

DERIVATIVE INSTRUMENTS (Details)	Mar. 31, 2014
	millions_of_decatherms
Basis and Index Related Purchase and Sales Contracts [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	30.8
Natural Gas (in MMdts) [Member] | Derivative Transaction Type, Purchase [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	30.3
Natural Gas (in MMdts) [Member] | Derivative Transaction Type, Sale [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	20.4
Electricity (in mwh) [Member] | Derivative Transaction Type, Purchase [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	1,000,000
Electricity (in mwh) [Member] | Derivative Transaction Type, Sale [Member]	'
Derivative [Line Items]	'
Outstanding derivative contracts notional amount	1,000,000

DERIVATIVE_INSTRUMENTS_2_Detai

DERIVATIVE INSTRUMENTS 2 (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	$76,562	$82,778
Fair value Derivative Liabilities	118,056	106,800
Not Designated as Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	76,562	82,778
Fair value Derivative Liabilities	118,056	106,800
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-Current [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	58,123	56,327
Fair value Derivative Liabilities	89,892	77,993
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-NonCurrent [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	18,439	26,451
Fair value Derivative Liabilities	20,274	22,131
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$7,890	$6,676

DERIVATIVE_INSTRUMENTS_3_Detai

DERIVATIVE INSTRUMENTS 3 (Details) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Commodity Contract [Member]	'		'
Offsetting Derivative Assets [Abstract]	'		'
Gross amounts of recognized assets/liabilities	$76,562		$82,778
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	76,562		82,778
Gross amounts not offset in the balance sheet, Financial Instruments	-39,526	[1]	-28,082	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		-498
Net amount	37,036		54,198
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-110,166		-100,124
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-110,166		-100,124
Gross amounts not offset in the balance sheet, Financial Instruments	39,526	[2]	28,082	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	17,275		29,639
Net amount	-53,365		-42,403
Interest Rate Contract [Member]	'		'
Offsetting Derivative Liabilities [Abstract]	'		'
Gross amounts of recognized assets/liabilities	-7,890		-6,676
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-7,890		-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	($7,890)		($6,676)
[1]	The balances at MarchB 31, 2014 and DecemberB 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at MarchB 31, 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
	Mar. 31, 2014		Mar. 31, 2013
Interest Rate Contracts [Abstract]	'		'
Losses recognized in AOCL on effective portion	$0		$0
Losses reclassified from AOCL into income	-112,000	[1]	-112,000	[1]
Gains (losses) recognized in income on ineffective portion	0	[1]	0	[1]
Losses on energy related commodity contracts	-28,601,000	[2]	-7,049,000	[2]
(Losses) gains on interest rate contracts	-214,000	[1]	525,000	[1]
Total	-28,815,000		-6,524,000
Net realized gains (losses), derivative instruments, energy-related contracts	2,400,000		-1,500,000
Fair value derivative instruments with credit-risk-related features	38,400,000		'
Additional collateral, aggregate fair value	$28,300,000		'
[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

In Thousands, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Level 3 [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Total [Member]

Total [Member]

Level 1 [Member]

Level 1 [Member]

Level 2 [Member]

Level 2 [Member]

Level 3 [Member]

Level 3 [Member]

Assets [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Available-for-Sale Securities

'

'

'

$8,829

[1]

$8,716

[1]

$8,829

[1]

$8,716

[1]

$0

[1]

$0

[1]

$0

[1]

$0

[1]

Derivatives - Energy Related Assets

'

'

'

76,562

[2]

82,778

[2]

7,109

[2]

4,385

[2]

28,935

[2]

27,182

[2]

40,518

[2]

51,211

[2]

Total Assets

'

'

'

85,391

91,494

15,938

13,101

28,935

27,182

40,518

51,211

Liabilities [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Derivatives - Energy Related Liabilities

'

'

'

110,166

[2]

100,124

[2]

5,732

[2]

4,236

[2]

58,945

[2]

52,772

[2]

45,489

[2]

43,116

[2]

Derivatives - Other

'

'

'

7,890

[3]

6,676

[3]

0

[3]

0

[3]

7,890

[3]

6,676

[3]

0

[3]

0

[3]

Total Liabilities

'

'

'

118,056

106,800

5,732

4,236

66,835

59,448

45,489

43,116

Changes in significant unobservable inputs [Roll forward]

'

'

'

'

'

'

'

'

'

'

'

Balance at beginning of period

8,095

2,762

'

'

'

'

'

'

'

'

'

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

-12,124

-701

-12,100

'

'

'

'

'

'

'

'

Settlements

-942

-434

'

'

'

'

'

'

'

'

'

Balance at end of period

($4,971)

$1,627

'

'

'

'

'

'

'

'

'

[1]

Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy.

[2]

Derivatives b Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. 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.

FAIR_VALUE_OF_FINANCIAL_ASSETS3

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES, LEVEL THREE INPUTS (Details) (Forward Contracts [Member], Fair Value, Inputs, Level 3 [Member], USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Natural Gas [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Assets	$31,078	$41,444
Liabilities	38,549	36,043
Electricity [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Assets	9,440	9,767
Liabilities	$6,940	$7,073
Minimum [Member] | Natural Gas [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Forward price (in dollars per dt)	-2.01	-1.75
Maximum [Member] | Natural Gas [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Forward price (in dollars per dt)	4.7	6.05
Weighted Average [Member] | Natural Gas [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Forward price (in dollars per dt)	-0.78	-0.79
On-Peak [Member] | Minimum [Member] | Electricity [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	8.06%	8.06%
On-Peak [Member] | Maximum [Member] | Electricity [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	100.00%	100.00%
On-Peak [Member] | Weighted Average [Member] | Electricity [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	55.03%	54.55%
Off-Peak [Member] | Minimum [Member] | Electricity [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	0.00%	0.00%
Off-Peak [Member] | Maximum [Member] | Electricity [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	91.94%	91.94%
Off-Peak [Member] | Weighted Average [Member] | Electricity [Member]	'	'
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]	'	'
Fixed electric load profile	44.97%	45.45%

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (South Jersey Gas Company [Member], USD $)	1 Months Ended
	Jul. 31, 2012	Jan. 31, 2014
		Mortgages [Member]
Debt Instrument [Line Items]	'	'
Debt face amount	'	$30,000,000
Investment requested to be recovered through CIRT III, annual amount of AIRP	$0.04	'

ACCUMULATED_OTHER_COMPREHENSIV2

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	($20,760)	[1]	'
Other comprehensive income before reclassifications	62		'
Amounts reclassified from AOCL	48	[2]	'
Other Comprehensive Income - Net of Tax	110	[1]	4,806	[1]
Ending balance	-20,650	[1]	'
Combined statutory tax rate	41.00%		41.00%
Postretirement Liability Adjustment [Member]	'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	-18,503	[1]	'
Other comprehensive income before reclassifications	0		'
Amounts reclassified from AOCL	0	[2]	'
Other Comprehensive Income - Net of Tax	0		'
Ending balance	-18,503	[1]	'
Unrealized Gain (Loss) on Derivatives-Other [Member]	'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	-2,697	[1]	'
Other comprehensive income before reclassifications	0		'
Amounts reclassified from AOCL	66	[2]	'
Other Comprehensive Income - Net of Tax	66		'
Ending balance	-2,631	[1]	'
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]	'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	397	[1]	'
Other comprehensive income before reclassifications	62		'
Amounts reclassified from AOCL	0	[2]	'
Other Comprehensive Income - Net of Tax	62		'
Ending balance	459	[1]	'
Other Comprehensive Income (Loss) of Affiliated Companies [Member]	'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'
Beginning balance	43	[1]	'
Other comprehensive income before reclassifications	0		'
Amounts reclassified from AOCL	-18	[2]	'
Other Comprehensive Income - Net of Tax	-18		'
Ending balance	$25	[1]	'
[1]	Determined using a combined statutory tax rate of 41%.
[2]	See table below.

ACCUMULATED_OTHER_COMPREHENSIV3

ACCUMULATED OTHER COMPREHENSIVE LOSS 2 (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Interest Charges	$7,084		$4,708
Equity in Loss of Affiliated Companies	-2,286		31
Income Tax Benefit (Expense)	11,869		7,772
(Loss) Income from Continuing Operations	-48,211		-43,337
Reclassification out of Accumulated Other Comprehensive Income [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
(Loss) Income from Continuing Operations	48		'
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Gain (Loss) on Derivatives-Other [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Interest Charges	112		'
Income Tax Benefit (Expense)	-46	[1]	'
(Loss) Income from Continuing Operations	66		'
Reclassification out of Accumulated Other Comprehensive Income [Member] | Other Comprehensive Income (Loss) of Affiliated Companies [Member]	'		'
Reclassification out of Accumulated Other Comprehensive Income [Line Items]	'		'
Equity in Loss of Affiliated Companies	-31		'
Income Tax Benefit (Expense)	13	[1]	'
(Loss) Income from Continuing Operations	($18)		'
[1]	Determined using a combined statutory tax rate of 41%.