South Jersey Industries (SJIIU) 10-Q 8 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	3 Months Ended
	Mar. 31, 2015	1-May-15
Document and Entity Information [Abstract]
Entity Registrant Name	SOUTH JERSEY INDUSTRIES INC
Entity Central Index Key	91928
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding		34,228,382

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (USD $)	3 Months Ended		0 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	8-May-15
Operating Revenues:
Utility	$266,530	$210,329
Nonutility	116,422	139,872
Total Operating Revenues	382,952	350,201
Cost of Sales - (Excluding depreciation)
- Utility	144,974	103,077
- Nonutility	96,733	125,061
Operations	41,861	39,350
Maintenance	3,998	3,259
Depreciation	16,819	14,991
Energy and Other Taxes	2,196	1,953
Total Operating Expenses	306,581	287,691
Operating Income	76,371	62,510
Other Income and Expense	2,241	2,368
Interest Charges	-8,601	-7,084
Income Before Income Taxes	70,011	57,794
Income Taxes	-16,613	-11,869
Equity in Earnings of Affiliated Companies	455	2,286
Income from Continuing Operations	53,853	48,211
Loss from Discontinued Operations - (Net of tax benefit)	-276	-313
Net Income	$53,577	$47,898
Basic Earnings Per Common Share:
Continuing Operations (in dollars per share)	$0.79	$0.74
Discontinued Operations (in dollars per share)	$0	($0.01)
Basic Earnings Per Common Share (in dollars per share)	$0.79	$0.73
Average Shares of Common Stock Outstanding - Basic (in shares)	68,397	65,530
Diluted Earnings Per Common Share:
Continuing Operations (in dollars per share)	$0.79	$0.74
Discontinued Operations (in dollars per share)	$0	($0.01)
Diluted Earnings Per Common Share (in dollars per share)	$0.79	$0.73
Average Shares of Common Stock Outstanding - Diluted (in shares)	68,618	65,684
Dividends Declared per Common Share (in dollars per share)	$0.25	$0.24
Subsequent Event
Diluted Earnings Per Common Share:
Stockholders' Equity Note, Stock Split, Conversion Ratio			2

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Net Income	$53,577		$47,898
Other Comprehensive Income, Net of Tax:
Unrealized Gain on Available-for-Sale Securities	88	[1]	62	[1]
Unrealized Gain on Derivatives - Other	8	[1]	66	[1]
Other Comprehensive Loss of Affiliated Companies	-95	[1]	-18	[1]
Other Comprehensive Income - Net of Tax	1	[1]	110	[1]
Comprehensive Income	$53,578		$48,008
[1]	.

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Combined statutory tax rate	40.00%	41.00%

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Statement of Cash Flows [Abstract]
Net Cash Provided by Operating Activities	$34,936	$49,232
Cash Flows from Investing Activities:
Capital Expenditures	-54,307	-60,254
Net Proceeds from Sale of Restricted Investments in Margin Account	4,829	7,444
Purchase of Available-for-Sale Securities	-6,059	0
Investment in Long-Term Receivables	-4,658	-2,053
Proceeds from Long-Term Receivables	1,808	1,981
Purchase of Company Owned Life Insurance	-356	-230
Investment in Affiliate	-717	0
Advances on Notes Receivable - Affiliate	-1,265	-342
Repayment of Notes Receivable - Affiliate	275	3,228
Net Cash Used in Investing Activities	-60,450	-50,226
Cash Flows from Financing Activities:
Net Borrowings from (Repayments of) Short-Term Credit Facilities	26,700	-29,600
Proceeds from Issuance of Long-Term Debt	0	30,000
Payments for Issuance of Long-Term Debt	0	-210
Proceeds from Sale of Common Stock	1,857	5,157
Net Cash Provided by Financing Activities	28,557	5,347
Net Increase in Cash and Cash Equivalents	3,043	4,353
Cash and Cash Equivalents at Beginning of Period	4,171	3,818
Cash and Cash Equivalents at End of Period	$7,214	$8,171

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
Property, Plant and Equipment:
Utility Plant, at original cost	$2,042,333		$2,002,966
Accumulated Depreciation	-419,223		-413,597
Nonutility Property and Equipment, at cost	626,875		622,079
Accumulated Depreciation	-84,524		-77,345
Property, Plant and Equipment - Net	2,165,461		2,134,103
Investments:
Available-for-Sale Securities	15,245		8,922
Restricted	60,623		65,451
Investment in Affiliates	67,754		68,351
Total Investments	143,622		142,724
Current Assets:
Cash and Cash Equivalents	7,214		4,171
Accounts Receivable	322,803		251,892
Unbilled Revenues	63,547		62,608
Provision for Uncollectibles	-9,383		-7,910
Notes Receivable - Affiliate	15,921		14,657
Natural Gas in Storage, average cost	38,925		63,246
Materials and Supplies, average cost	2,112		2,125
Deferred Income Taxes - Net	56,696		57,748
Prepaid Taxes	4,429		14,106
Derivatives - Energy Related Assets	52,441		85,368
Other Prepayments and Current Assets	25,453		18,686
Total Current Assets	580,158		566,697
Regulatory and Other Noncurrent Assets:
Regulatory Assets	335,009		357,160
Derivatives - Energy Related Assets	15,402		13,905
Unamortized Debt Issuance Costs	9,449		9,795
Notes Receivable - Affiliate	36,525		36,799
Contract Receivables	21,607		19,236
Notes Receivable	7,882		7,882
Other	61,607		61,124
Total Regulatory and Other Noncurrent Assets	487,481		505,901
Total Assets	3,376,722		3,349,425
Equity:
Common Stock	85,530		85,418
Premium on Common Stock	440,882		438,384
Treasury Stock (at par)	-284		-330
Accumulated Other Comprehensive Loss	-30,257	[1]	-30,258	[1]
Retained Earnings	475,614		439,218
Total Equity	971,485		932,432
Long-Term Debt	859,491		859,491
Total Capitalization	1,830,976		1,791,923
Current Liabilities:
Notes Payable	272,400		245,700
Current Portion of Long-Term Debt	149,909		149,909
Accounts Payable	221,230		272,998
Customer Deposits and Credit Balances	16,052		17,958
Environmental Remediation Costs	38,186		30,430
Taxes Accrued	9,197		2,328
Derivatives - Energy Related Liabilities	81,779		109,744
Dividends Payable	17,191		0
Interest Accrued	6,578		7,088
Pension Benefits	1,515		1,550
Other Current Liabilities	7,584		12,480
Total Current Liabilities	821,621		850,185
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	356,380		344,520
Investment Tax Credits	111		149
Pension and Other Postretirement Benefits	98,232		115,373
Environmental Remediation Costs	90,159		97,742
Asset Retirement Obligations	42,599		42,502
Derivatives - Energy Related Liabilities	24,522		19,926
Derivatives - Other	12,036		10,732
Regulatory Liabilities	66,526		41,899
Finance Obligation	19,420		19,659
Other	14,140		14,815
Total Deferred Credits and Other Noncurrent Liabilities	724,125		707,317
Commitments and Contingencies
Total Capitalization and Liabilities	$3,376,722		$3,349,425
[1]	For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	3 Months Ended
	Mar. 31, 2015
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.
	▪	SJI Midstream, LLC was formed in 2014 to invest in a project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.
	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 2014 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.
	On February 26, 2015, the Board of Directors approved an amendment to SJI's Certificate of Incorporation to increase the authorized number of shares of common stock from 60,000,000 shares to 120,000,000 shares. The principal purpose of the increase is to permit a two-for-one split of all the issued shares of SJI's common stock, to be effected pursuant to a stock dividend of one share of common stock for each outstanding share of common stock, payable May 8, 2015 to shareholders of record at the close of business on April 17, 2015. All references to number of shares and per share information in the condensed consolidated financial statements and related notes have been retroactively adjusted to reflect this stock split.
	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 energy and other taxes and totaled $0.6 million and $0.4 million for the three months ended March 31, 2015 and 2014, respectively.
	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, 2015 and 2014, 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 charges were recorded during the three months ended March 31, 2015 or 2014. As of both March 31, 2015 and December 31, 2014, $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, 2015 and December 31, 2014, SJI held 227,432 and 263,578 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 2015 or 2014 had, or is expected to have, a material impact on the condensed consolidated financial statements.
	In April 2014, the FASB issued ASU 2014-08, Presentation of Financial Statements and Property, Plant and Equipment: Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. This ASU changes the presentation of discontinued operations on the statements of income and other requirements for reporting discontinued operations. Under the new standard, only those disposals of components of an entity that represent a strategic shift that has (or will have) a major effect on an entity's operations and financial results should be reported as a discontinued operation. This ASU also requires additional disclosures about discontinued operations and disposal of an individually significant component of an entity that does not qualify for discontinued operations. The new accounting guidance is effective prospectively to all disposals or classifications as held for sale of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. The revised guidance should not be applied to a component of an entity or a business that is classified as held for sale before the effective date. As such, the adoption of this guidance did not have an impact on the Company's financial statement results.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606), This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.
	In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption.
	In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810)—Amendments to the Consolidation Analysis, which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard is effective for annual periods beginning after December 15, 2015 and interim periods therein, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.
	In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard is effective for annual periods beginning after December 15, 2015 and interim periods therein. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

STOCKBASED_COMPENSATION_PLAN

STOCK-BASED COMPENSATION PLAN	3 Months Ended
	Mar. 31, 2015
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 (Plan), shares may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. This plan terminated on January 26, 2015. On January 23, 2015, the Board of Directors approved a new stock-based compensation plan. The new plan was approved by shareholders on April 30, 2015. No options were granted or outstanding during the three months ended March 31, 2015 and 2014.  No stock appreciation rights have been issued under the plan. During the three months ended March 31, 2015 and 2014, SJI granted 151,354 and 136,526 restricted shares, respectively, to Officers and other key employees under the 1997 plan prior to its termination.  Performance-based 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 200% of the original share units granted. In 2015, SJI also granted time-based shares of restricted stock, one-third of which vests annually over a three-year period and is limited to 100% payout if the service requirement is met. In January 2015, Officers and other key employees were granted 45,406 shares of time-based restricted stock, which are included in the shares noted above.
	Grants containing market-based performance targets use SJI's total shareholder return (TSR) relative to a peer group to measure performance. As TSR-based grants are contingent upon market and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant on a straight-line basis over the requisite three-year period of each award. In addition, SJI identifies specific forfeitures of share-based awards, and compensation expense is adjusted accordingly over the requisite service period. Compensation expense is not adjusted based on the actual achievement of performance goals. The fair value of TSR-based restricted stock awards on the date of grant is estimated using a Monte Carlo simulation model.
	Through 2014, grants containing earnings-based targets were based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance. Beginning in 2015, earning-based performance targets include predefined EPS and return on equity (ROE) goals to measure performance. As EPS-based and ROE-based grants are contingent upon performance and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant over the requisite three-year period of each award. The fair value is measured as the market price at the date of grant. The initial accruals of compensation expense are based on the estimated number of shares expected to vest, assuming the requisite service is rendered and probable outcome of the performance condition is achieved. That estimate is revised if subsequent information indicates that the actual number of shares is likely to differ from previous estimates. Compensation expense is ultimately adjusted based on the actual achievement of service and performance targets.
	During the three months ended March 31, 2015 and 2014, SJI granted 25,398 and 23,220 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.
	The following table summarizes the nonvested restricted stock awards outstanding at March 31, 2015 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. 2013 - TSR		49,514			$	22.19		21.1	%	0.4	%
		Jan. 2013 - EPS		49,514			$	25.59		N/A		N/A
		Jan. 2014 - TSR		62,192			$	21.31		20	%	0.8	%
		Jan. 2014 - EPS		62,192			$	27.22		N/A		N/A
		Jan. 2015 - TSR		42,378			$	26.31		16	%	1.1	%
		Jan. 2015 - EPS, ROE, Time		108,976			$	29.47		N/A		N/A
	Directors -	Jan. 2015		25,398			$	29.34		N/A		N/A
	Expected volatility is based on the actual volatility of SJI’s share price over the preceding three-year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three-year term of the Officers’ and other key employees’ restricted shares. As notional dividend equivalents are credited to the holders during the three-year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant.
	The following table summarizes the total stock-based compensation cost for the three months ended March 31, 2015 and 2014 (in thousands):
		Three Months Ended
		March 31,
		2015			2014
	Officers & Key Employees	$	799		$	581
	Directors	186			158
	Total Cost	985			739
	Capitalized	(91		)	(70		)
	Net Expense	$	894		$	669
	As of March 31, 2015, there was $6.8 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the Plan. That cost is expected to be recognized over a weighted average period of 2.1 years.
	The following table summarizes information regarding restricted stock award activity during the three months ended March 31, 2015, excluding accrued dividend equivalents:
		Officers &Other Key Employees			Directors			Weighted
								Average
								Fair Value
	Nonvested Shares Outstanding, January 1, 2015	223,876			23,220			$	24.4
	Granted	151,354			25,398			$	28.69
	Cancelled/Forfeited	(464	)		—			$	24.13
	Vested	—			(23,220	)		$	27.26
	Nonvested Shares Outstanding, March 31, 2015	374,766			25,398			$	26.13
	Performance targets during the three-year vesting period were not attained for the January 2011 grant that vested at December 31, 2013 or the January 2012 grant that vested at December 31, 2014. As a result, no shares were awarded in 2014 or 2015. During the three months ended March 31, 2015 and 2014, SJI granted 25,398 and 23,220 shares to its Directors at a market value of $0.7 million and $0.6 million, respectively. The Company has a policy of issuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of the Plan. 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, 2015
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, 2015 and 2014, were (in thousands, except per share amounts):
		Three Months Ended
		March 31,
		2015			2014
	Loss Before Income Taxes:
	Sand Mining	$	(347	)	$	(380	)
	Fuel Oil	(66		)	(102		)
	Income Tax Benefits	137			169
	Loss from Discontinued Operations — Net	$	(276	)	$	(313	)
	Earnings (Loss) Per Common Share from
	Discontinued Operations — Net:
	Basic and Diluted	$	—		$	(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.
	During the first three months of 2015, the Company made investments in, and provided net advances to, unconsolidated affiliates of $1.7 million. During the first three months of 2014, the Company received net repayments from unconsolidated affiliates of $2.9 million.  As of March 31, 2015 and December 31, 2014, the outstanding balance on these Notes Receivable – Affiliate was $52.4 million and $51.5 million, respectively. Approximately $39.4 million of these notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025. The remaining $13.0 million of these notes are unsecured and accrue interest at variable rates.
	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, 2015, the Company had a net asset of approximately $66.9 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, 2015 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $120.2 million plus the guarantees discussed in Note 11.

COMMON_STOCK

COMMON STOCK	3 Months Ended
	Mar. 31, 2015
Common Stock [Abstract]
COMMON STOCK	COMMON STOCK:
	The following shares were issued and outstanding:
		2015
	Beginning Balance, January 1 (See Note 1)	68,334,860
	New Issues During the Period:
	Dividend Reinvestment Plan	63,690
	Stock-Based Compensation Plan	25,398
	Ending Balance, March 31	68,423,948
	The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $2.6 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 220,762 and 154,448 for the three months ended March 31, 2015 and 2014, 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 $1.9 million and $5.2 million of equity capital through the DRP during the three months ended March 31, 2015 and 2014, respectively.

FINANCIAL_INSTRUMENTS

FINANCIAL INSTRUMENTS	3 Months Ended
	Mar. 31, 2015
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 both March 31, 2015 and December 31, 2014, the escrowed proceeds, including interest earned, totaled $1.7 million.
	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, 2015 and December 31, 2014, the balances in these accounts totaled $58.9 million and $63.7 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at March 31, 2015 and December 31, 2014, which would be included in Level 1 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities).
	INVESTMENT IN AFFILIATES - During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex.
	In June 2014 the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. The Energenic subsidiaries are currently providing limited services to the complex under a short-term agreement with the new owner.
	As a result, Management has evaluated the carrying value of the investment in this project and a related note receivable. Based on the current situation, and considering that the Energenic subsidiaries have reserved for a portion of the receivables from the complex, Management believes the estimated fair value of this investment continues to be in excess of the respective carrying values as of March 31, 2015. Estimating the fair value of an investment is highly judgmental and involves the use of significant estimates and assumptions. Actual results may differ significantly from those used to develop Management’s estimate.
	As of March 31, 2015, the Company, through its investment in Energenic, had a remaining net asset of approximately $15.1 million included in Investment in Affiliates on the condensed consolidated balance sheets related to this project. In addition, the Company had approximately $13.9 million included in Notes Receivable - Affiliate on the condensed consolidated balance sheets, due from an Energenic subsidiary, which is secured by certain assets of the central energy center. This note is subject to a reimbursement agreement that secures reimbursement for the Company, from its joint venture partner, of a proportionate share of any amounts that are not repaid.
	Management will continue to monitor the situation surrounding the complex, including the status of a permanent or long-term energy services agreement between the Energenic subsidiary and the complex, and will evaluate the carrying value of the investment and the note receivable as future events occur.
	LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources.  The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest.  The carrying amounts of such loans were $14.9 million and $15.0 million as of March 31, 2015 and December 31, 2014, respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the condensed consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.2 million and $1.3 million as of March 31, 2015 and December 31, 2014, respectively.  The annualized amortization to interest is not material to the Company’s condensed consolidated financial statements.  The carrying amounts of these receivables approximate their fair value at March 31, 2015 and December 31, 2014, 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, 2015, approximately $11.6 million, or 17.3%, of the current and noncurrent Derivatives – Energy Related Assets are transacted with one counterparty. This counterparty has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assigned to SJI in the event of default by the 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, 2015 and December 31, 2014. 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 $19.4 million and $19.7 million, net of amortization, within Finance Obligation on the condensed consolidated balance sheets at March 31, 2015 and December 31, 2014, 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, 2015 and December 31, 2014, 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, 2015 and December 31, 2014, were $1,068.9 million and $1,058.5 million, respectively.  The carrying amounts of SJI's long-term debt, including current maturities, as of both March 31, 2015 and December 31, 2014, were $1,009.4 million.

SEGMENTS_OF_BUSINESS

SEGMENTS OF BUSINESS	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
SEGMENTS OF BUSINESS	SEGMENTS OF BUSINESS:
	SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. 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.
	SJI groups its non-utility operations into two categories: 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. 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,
		2015			2014
	Operating Revenues:
	Gas Utility Operations	$	267,658		$	210,545
	Energy Group:
	Wholesale Energy Operations	35,345			35,372
	Retail Gas and Other Operations	38,078			51,506
	Retail Electric Operations	29,777			40,393
	Subtotal Energy Group	103,200			127,271
	Energy Services:
	On-Site Energy Production	13,572			11,346
	Appliance Service Operations	2,357			2,654
	Subtotal Energy Services	15,929			14,000
	Corporate & Services	9,086			7,871
	Subtotal	395,873			359,687
	Intersegment Sales	(12,921		)	(9,486		)
	Total Operating Revenues	$	382,952		$	350,201
		Three Months Ended
		March 31,
		2015			2014
	Operating Income (Loss):
	Gas Utility Operations	$	73,189		$	63,440
	Energy Group:
	Wholesale Energy Operations	330			(1,655		)
	Retail Gas and Other Operations	3,087			1,968
	Retail Electric Operations	(182		)	(54		)
	Subtotal Energy Group	3,235			259
	Energy Services:
	On-Site Energy Production	(482		)	(1,260		)
	Appliance Service Operations	(52		)	(95		)
	Subtotal Energy Services	(534		)	(1,355		)
	Corporate and Services	481			166
	Total Operating Income	$	76,371		$	62,510
	Depreciation and Amortization:
	Gas Utility Operations	$	14,167		$	12,676
	Energy Group:
	Wholesale Energy Operations	32			40
	Retail Gas and Other Operations	20			22
	Subtotal Energy Group	52			62
	Energy Services:
	On-Site Energy Production	7,051			5,775
	Appliance Service Operations	74			67
	Subtotal Energy Services	7,125			5,842
	Corporate and Services	242			219
	Total Depreciation and Amortization	$	21,586		$	18,799
	Interest Charges:
	Gas Utility Operations	$	5,190		$	4,342
	Energy Group:
	Wholesale Energy Operations	242			121
	Retail Gas and Other Operations	73			126
	Subtotal Energy Group	315			247
	Energy Services:
On-Site Energy Production	2,315			2,128
Corporate and Services	2,988			1,850
Subtotal	10,808			8,567
Intersegment Borrowings	(2,207		)	(1,483		)
Total Interest Charges	$	8,601		$	7,084
	Three Months Ended
	March 31,
	2015			2014
Income Taxes:
Gas Utility Operations	$	26,172		$	22,527
Energy Group:
Wholesale Energy Operations	867			(553		)
Retail Gas and Other Operations	1,576			936
Retail Electric Operations	(74		)	(22		)
Subtotal Energy Group	2,369			361
Energy Services:
On-Site Energy Production	(12,047		)	(11,025		)
Appliance Service Operations	(8		)	(23		)
Subtotal Energy Services	(12,055		)	(11,048		)
Corporate and Services	127			29
Total Income Taxes	$	16,613		$	11,869
Property Additions:
Gas Utility Operations	$	43,326		$	32,531
Energy Group:
Wholesale Energy Operations	4			2
Retail Gas and Other Operations	729			168
Subtotal Energy Group	733			170
Energy Services:
On-Site Energy Production	4,381			9,149
Appliance Service Operations	116			—
Subtotal Energy Services	4,497			9,149
Corporate and Services	1,064			778
Total Property Additions	$	49,620		$	42,628
	March 31, 2015			December 31, 2014
Identifiable Assets:
Gas Utility Operations	$	2,291,920		$	2,185,672
Energy Group:
Wholesale Energy Operations	294,484			366,119
Retail Gas and Other Operations	52,195			53,073
Retail Electric Operations	25,311			23,682
Subtotal Energy Group	371,990			442,874
Energy Services:
On-Site Energy Production	661,485			675,937
Appliance Service Operations	3,265			3,105
Subtotal Energy Services	664,750			679,042
Discontinued Operations	1,755			1,758
Corporate and Services	563,649			527,691
Intersegment Assets	(517,342		)	(487,612		)
Total Identifiable Assets	$	3,376,722		$	3,349,425

RATES_AND_REGULATORY_ACTIONS

RATES AND REGULATORY ACTIONS	3 Months Ended
	Mar. 31, 2015
Public Utilities, General Disclosures [Abstract]
RATES AND REGULATORY ACTIONS	RATES AND REGULATORY ACTIONS:
	SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU).
	Effective October 1, 2014, the BPU granted SJG a base rate increase of $20.0 million, which was predicated in part upon a 7.10% rate of return on rate base that included a 9.75% return on common equity. The $20.0 million base rate increase includes approximately $7.5 million associated with previously approved Accelerated Infrastructure Replacement Program (AIRP) investments that were rolled into rate base. SJG was also permitted to recover regulatory assets contained in its petition and reduce its composite depreciation rate from 2.4% to 2.1%.
	In January 2015, SJG filed a petition with the BPU seeking to continue offering energy efficiency programs through June 2018 with a proposed budget of $56.0 million and with the same rate recovery mechanism that exists for its current energy efficiency programs.
	There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2014. See Note 10 to the Consolidated Financial Statements in Item 8 of SJI's Annual Report on Form 10-K for the year ended December 31, 2014.

REGULATORY_ASSETS_REGULATORY_L

REGULATORY ASSETS & REGULATORY LIABILITIES	3 Months Ended
	Mar. 31, 2015
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, 2014 which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014.
	Regulatory Assets consisted of the following items (in thousands):
		March 31, 2015		December 31, 2014
	Environmental Remediation Costs:
	Expended - Net	$	28,057	$	29,540
	Liability for Future Expenditures	124,761		124,308
	Deferred Asset Retirement Obligation Costs	31,604		31,584
	Deferred Pension and Other Postretirement Benefit Costs	99,040		99,040
	Deferred Gas Costs - Net	20,291		32,202
	Societal Benefit Costs Receivable	—		385
	Deferred Interest Rate Contracts	8,330		7,325
	Energy Efficiency Tracker	1,782		11,247
	Pipeline Supplier Service Charges	5,025		5,441
	Pipeline Integrity Cost	3,439		3,431
	AFUDC - Equity Related Deferrals	10,987		10,781
	Other Regulatory Assets	1,693		1,876
	Total Regulatory Assets	$	335,009	$	357,160
	DEFERRED GAS COSTS - NET - Over/under collections of gas costs are monitored through SJG's Basic Gas Supply Service (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 reduction in deferred gas costs from December 31, 2014 was due to gas costs recovered from customers exceeding the actual cost of the commodity incurred during the first three months of 2015 as a result of more normal gas prices. SJG's BGSS mechanism is designed to over-collect gas costs during the winter season when usage is highest.
	ENERGY EFFICIENCY TRACKER - This regulatory asset primarily represents energy efficiency measures installed in customer homes and businesses. The decrease from December 31, 2014 is due to higher recoveries in the first three months of 2015 due to high level of recoveries resulting from extremely cold weather.
	Regulatory Liabilities consisted of the following items (in thousands):
		March 31, 2015		December 31, 2014
	Excess Plant Removal Costs	$	35,762	$	35,940
	Conservation Incentive Program Payable	21,825		4,700
	Societal Benefit Costs	8,939		—
	Other Regulatory Liabilities	—		1,259
	Total Regulatory Liabilities	$	66,526	$	41,899
	EXCESS PLANT REMOVAL COSTS - Represents amounts accrued in excess of actual utility plant removal costs incurred to date. The decrease in the balance from year end is due to an amortization as a credit to depreciation expense as required as part of SJG's September 2014 base rate increase.
	CONSERVATION INCENTIVE PROGRAM (CIP) PAYABLE – 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 2014 and more notably during the first three months of 2015 resulting in a payable. This is primarily the result of extremely cold weather experienced in the region.
	SOCIETAL BENEFIT COSTS (SBC) - This regulatory liability primarily represents the excess recoveries over the expenses incurred under the New Jersey Clean Energy Program which is a mechanism designed to recover costs associated with energy efficiency and renewable energy programs. The change from a $0.4 million regulatory asset to a $8.9 million regulatory liability is due to current SBC rates which are producing revenue greater than SBC expenses. In July 2014, SJG made its annual 2014-2015 SBC filing requesting a decrease in SBC revenues, in part, to avoid this liability. The petition is currently pending.

PENSION_AND_OTHER_POSTRETIREME

PENSION AND OTHER POSTRETIREMENT BENEFITS	3 Months Ended
	Mar. 31, 2015
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, 2015 and 2014, 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,
		2015			2014
	Service Cost	$	1,443		$	1,285
	Interest Cost	2,770			2,695
	Expected Return on Plan Assets	(3,699		)	(3,265		)
	Amortizations:
	Prior Service Cost	53			43
	Actuarial Loss	2,656			1,426
	Net Periodic Benefit Cost	3,223			2,184
	Capitalized Benefit Costs	(1,239		)	(854		)
	Total Net Periodic Benefit Expense	$	1,984		$	1,330
		Other Postretirement Benefits
		Three Months Ended
		March 31,
		2015			2014
	Service Cost	$	327		$	250
	Interest Cost	771			740
	Expected Return on Plan Assets	(748		)	(687		)
	Amortizations:
	Prior Service Cost	152			38
	Actuarial Loss	384			243
	Net Periodic Benefit Cost	886			584
	Capitalized Benefit Costs	(256		)	(209		)
	Total Net Periodic Benefit Expense	$	630		$	375
	Capitalized benefit costs reflected in the table above relate to SJG’s construction program.
	SJI contributed $15.0 million to the pension plans in January 2015. No contributions were made to the pension plans during 2014. Payments related to the unfunded supplemental executive retirement plan (SERP) are expected to approximate $1.5 million in 2015. 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 for the year ended December 31, 2014, for additional information related to SJI’s pension and other postretirement benefits.

LINES_OF_CREDIT

LINES OF CREDIT	3 Months Ended
	Mar. 31, 2015
Line of Credit Facility [Abstract]
LINES OF CREDIT	LINES OF CREDIT:
	Credit facilities and available liquidity as of March 31, 2015 were as follows (in thousands):
	Company	Total Facility		Usage		Available Liquidity		Expiration Date
	SJG:
	Commercial Paper Program/Revolving Credit Facility	$	200,000	$	129,600	$	70,400	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-15
	Total SJG	210,000		129,600		80,400
	SJI:
	Revolving Credit Facility	400,000		156,400		243,600		February 2018 (A)
	Total SJI	400,000		156,400		243,600
	Total	$	610,000	$	286,000	$	324,000
	(A) Includes letters of credit outstanding in the amount of $13.6 million.
	The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 0.88% and 1.06% at March 31, 2015 and 2014, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the three months ended March 31, 2015 and 2014 were $274.1 million and $332.2 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the three months ended March 31, 2015 and 2014 were $329.4 million and $390.7 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, 2015.
	SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million.  The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes.  SJG uses the commercial paper program in tandem with its $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES:
	GUARANTEES — The Company has recorded a liability of $0.6 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, 2015 for the fair value of the following guarantees:
	SJI has guaranteed certain obligations of WC Landfill Energy, LLC (WCLE) and BC Landfill Energy, LLC (BCLE), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. WCLE and BCLE have entered into agreements through 2018 and 2027, respectively, with the respective county governments to lease and operate facilities that will produce electricity from landfill methane gas.  Although unlikely, the maximum amount that SJI could be obligated for, in the event that WCLE and BCLE do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due, is approximately $4.2 million each year.  SJI and its partner in these joint ventures have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.  SJI holds variable interests in WCLE and BCLE but is not the primary beneficiary.
	In December 2013, SJI entered into agreements to guarantee certain obligations of WCLE, SC Landfill Energy, LLC, SX Landfill Energy, LLC, FC Landfill Energy, LLC, and AC Landfill Energy, LLC (collectively, the "Landfills"), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. The Landfills have entered into long-term debt agreements which run through 2020. Although unlikely, SJI could be liable through the guarantees for 50% of the outstanding debt along with any interest related to the debt in the event the Landfills do not meet minimum specified levels of operating performance and no mitigating action is taken, or the Landfills are unable to meet certain financial obligations as they become due. As of March 31, 2015, 50% of the currently outstanding debt is $8.6 million.
	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. As of March 31, 2015, SJI has guaranteed up to $2.4 million. 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. SJI holds variable interests in UMM but is not the primary beneficiary.
	As of March 31, 2015, SJI had issued $7.2 million of parental 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, 2015. 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 collective bargaining agreements that run through February 2017. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017.
	STANDBY LETTERS OF CREDIT — As of March 31, 2015, SJI provided $13.6 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.
	PENDING LITIGATION — The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.2 million and $2.9 million related to all claims in the aggregate as of March 31, 2015 and December 31, 2014, 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, 2014 as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014.

DERIVATIVE_INSTRUMENTS

DERIVATIVE INSTRUMENTS	3 Months Ended
	Mar. 31, 2015
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, 2015, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 55.9 MMdts (1 MMdts =ne million decatherms) of expected future purchases of natural gas, 45.7 MMdts of expected future sales of natural gas, 2.7 MMmwh (1 MMmwh =ne million megawatt hours) of expected future purchases of electricity and 2.7 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 315.3 MMdts.  These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives — Energy Related Assets or Derivatives — Energy Related Liabilities on the condensed consolidated balance sheets. The net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility.
	The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, some of which have been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the condensed consolidated balance sheets. Beginning in July 2012, hedge accounting was discontinued for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously included in Accumulated Other Comprehensive Loss (AOCL) on the consolidated balance sheets, will be reclassified into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026.
	There have been no significant changes to the Company’s active interest rate swaps since December 31, 2014 which are described in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014.
	The fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of March 31, 2015 and December 31, 2014, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	March 31, 2015						December 31, 2014
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	52,441		$	81,779		$	85,368		$	109,744
	Derivatives – Energy Related – Non-Current	15,402			24,522			13,905			19,926
	Interest rate contracts:
	Derivatives - Other	—			12,036			—			10,732
	Total derivatives not designated as hedging instruments under GAAP	67,843			118,337			99,273			140,402
	Total Derivatives	$	67,843		$	118,337		$	99,273		$	140,402
	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, 2015 and December 31, 2014, information related to these offsetting arrangements were as follows (in thousands):
	As of March 31, 2015
	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	$	67,843		$	—		$	67,843		$	(24,796	)	(A)	$	—	$	43,047
	Derivatives - Energy Related Liabilities	$	(106,301	)	$	—		$	(106,301	)	$	24,796		(B)	$	42,770	$	(38,735	)
	Derivatives - Other	$	(12,036	)	$	—		$	(12,036	)	$	—			$	—	$	(12,036	)
	As of December 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	$	99,273		$	—		$	99,273		$	(39,747	)	(A)	$	—	$	59,526
	Derivatives - Energy Related Liabilities	$	(129,670	)	$	—		$	(129,670	)	$	39,747		(B)	$	53,897	$	(36,026	)
	Derivatives - Other	$	(10,732	)	$	—		$	(10,732	)	$	—			$	—	$	(10,732	)
	(A) The balances at March 31, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at March 31, 2015 and December 31, 2014 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, 2015 and 2014 are as follows (in thousands):
		Three Months Ended
		March 31,
	Derivatives in Cash Flow Hedging Relationships under GAAP	2015			2014
	Interest Rate Contracts:
	Losses recognized in AOCL on effective portion	$	—		$	—
	Losses reclassified from AOCL into income (a)	$	(23	)	$	(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	2015			2014
	Losses on energy related commodity contracts (a)	$	(6,707	)	$	(28,601	)
	Losses on interest rate contracts (b)	(298		)	(214		)
	Total	$	(7,005	)	$	(28,815	)
	(a)  Included in Operating Revenues - Non Utility
	(b)  Included in Interest Charges
	Net realized loss of $2.6 million and net realized gain of $2.4 million associated with SJG's energy-related financial commodity contracts for the three months ended March 31, 2015 and 2014, respectively, are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy-related financial commodity contracts are deferred in Regulatory Assets or Liabilities, as applicable, and there is no impact to earnings.
	Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit risk-related contingent features that are in a liability position on March 31, 2015, is $36.3 million.  If the credit risk-related contingent features underlying these agreements were triggered on March 31, 2015, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $30.2 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, 2015
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, 2015	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	15,245			$	9,816			$	5,429	$	—
	Derivatives – Energy Related Assets (B)	67,843				12,154				29,681		26,008
		$	83,088			$	21,970			$	35,110	$	26,008
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	106,301			$	37,798			$	25,184	$	43,319
	Derivatives – Other (C)	12,036				—				12,036		—
		$	118,337			$	37,798			$	37,220	$	43,319
	As of December 31, 2014	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,922			$	5,952			$	2,970	$	—
	Derivatives – Energy Related Assets (B)	99,273				21,675				43,093		34,505
		$	108,195			$	27,627			$	46,063	$	34,505
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	129,670			$	49,009			$	40,548	$	40,113
	Derivatives – Other (C)	10,732				—				10,732		—
		$	140,402			$	49,009			$	51,280	$	40,113
	(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, 2015		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets	Liabilities
	Forward Contract - Natural Gas	$19,557	$38,607	Discounted Cash Flow	Forward price (per dt)	$(1.61) - $7.25 [$(0.28)]
	Forward Contract - Electric	$6,451	$4,712	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [56.75%]
					Fixed electric load profile (off-peak)	0.00% - 91.94% [43.25%]
	Type	Fair Value at December 31, 2014						Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets			Liabilities
	Forward Contract - Natural Gas	$	26,485		$	33,882		Discounted Cash Flow	Forward price (per dt)	$(2.04) - $7.83 [$(0.30)]
	Forward Contract - Electric	$	8,020		$	6,231		Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [55.97%]
									Fixed electric load profile (off-peak)	0.00% - 91.94% [44.03%]
	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three months ended March 31, 2015 and 2014, using significant unobservable inputs (Level 3), are as follows (in thousands):
		Three Months Ended				Three Months Ended March 31,2014
		31-Mar-15
	Balance at beginning of period	$	(5,608	)		$	8,095
	Other changes in fair value from continuing and new contracts, net	(16,438		)		(12,124		)
	Settlements	4,735				(942		)
	Balance at end of period	$	(17,311	)		$	(4,971	)
	Total losses for 2015 included in earnings for the three months ended March 31, 2015 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, 2015, are $16.4 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, 2015
Long-term Debt, Unclassified [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT:
	The Company did not issue or retire any long-term debt during the three months ended March 31, 2015.

ACCUMULATED_OTHER_COMPREHENSIV

ACCUMULATED OTHER COMPREHENSIVE LOSS	3 Months Ended
	Mar. 31, 2015
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, 2015 (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, 2015 (a)	$	(27,663	)	$	(2,450	)	$	(75	)	$	(70	)	$	(30,258	)
	Other comprehensive income before reclassifications	—			—			92			—			92
	Amounts reclassified from AOCL (b)	—			8			(4		)	(95		)	(91		)
	Net current period other comprehensive income (loss)	—			8			88			(95		)	1
	Balance at March 31, 2015 (a)	$	(27,663	)	$	(2,442	)	$	13		$	(165	)	$	(30,257	)
	(a) For 2015, determined using a combined average statutory tax rate of 40%. For 2014, 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, 2015:
		Amounts Reclassified from AOCL (in thousands)				Affected Line Item in the Condensed Consolidated Statements of Income
		Three Months Ended
		31-Mar-15
	Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	23			Interest Charges
	Income Taxes	(15		)		Income Taxes (a)
		$	8
	Unrealized Loss on Available-for-Sale Securities	$	(7	)		Other Income
	Income Taxes	3				Income Taxes (a)
		$	(4	)
	Loss of Affiliated Companies	$	(153	)		Equity in Loss of Affiliated Companies
	Income Taxes	58				Income Taxes (a)
		$	(95	)
	Losses from reclassifications for the period net of tax	$	(91	)

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
	Mar. 31, 2015
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.
	▪	SJI Midstream, LLC was formed in 2014 to invest in a project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.
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 2014 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.
	On February 26, 2015, the Board of Directors approved an amendment to SJI's Certificate of Incorporation to increase the authorized number of shares of common stock from 60,000,000 shares to 120,000,000 shares. The principal purpose of the increase is to permit a two-for-one split of all the issued shares of SJI's common stock, to be effected pursuant to a stock dividend of one share of common stock for each outstanding share of common stock, payable May 8, 2015 to shareholders of record at the close of business on April 17, 2015. All references to number of shares and per share information in the condensed consolidated financial statements and related notes have been retroactively adjusted to reflect this stock split.
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.
IMPAIRMENT OF LONG-LIVED ASSETS	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.
GAS EXPLORATION AND DEVELOPMENT	GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred.
TREASURY STOCK	TREASURY STOCK – SJI uses the par value method of accounting for treasury stock.
INCOME TAXES	INCOME TAXES — Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 740 - “Income Taxes”.  A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow through method, which may result in variations in the customary relationship between income taxes and pre-tax income for interim periods.
NEW ACCOUNTING PRONOUNCEMENTS	NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2015 or 2014 had, or is expected to have, a material impact on the condensed consolidated financial statements.
	In April 2014, the FASB issued ASU 2014-08, Presentation of Financial Statements and Property, Plant and Equipment: Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. This ASU changes the presentation of discontinued operations on the statements of income and other requirements for reporting discontinued operations. Under the new standard, only those disposals of components of an entity that represent a strategic shift that has (or will have) a major effect on an entity's operations and financial results should be reported as a discontinued operation. This ASU also requires additional disclosures about discontinued operations and disposal of an individually significant component of an entity that does not qualify for discontinued operations. The new accounting guidance is effective prospectively to all disposals or classifications as held for sale of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. The revised guidance should not be applied to a component of an entity or a business that is classified as held for sale before the effective date. As such, the adoption of this guidance did not have an impact on the Company's financial statement results.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606), This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.
	In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption.
	In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810)—Amendments to the Consolidation Analysis, which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard is effective for annual periods beginning after December 15, 2015 and interim periods therein, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.
	In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard is effective for annual periods beginning after December 15, 2015 and interim periods therein. Management is currently determining the impact that adoption of this guidance will have 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, 2015
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, 2015 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. 2013 - TSR		49,514			$	22.19		21.1	%	0.4	%
		Jan. 2013 - EPS		49,514			$	25.59		N/A		N/A
		Jan. 2014 - TSR		62,192			$	21.31		20	%	0.8	%
		Jan. 2014 - EPS		62,192			$	27.22		N/A		N/A
		Jan. 2015 - TSR		42,378			$	26.31		16	%	1.1	%
		Jan. 2015 - EPS, ROE, Time		108,976			$	29.47		N/A		N/A
	Directors -	Jan. 2015		25,398			$	29.34		N/A		N/A
Summary of the total stock-based compensation cost for the period	The following table summarizes the total stock-based compensation cost for the three months ended March 31, 2015 and 2014 (in thousands):
		Three Months Ended
		March 31,
		2015			2014
	Officers & Key Employees	$	799		$	581
	Directors	186			158
	Total Cost	985			739
	Capitalized	(91		)	(70		)
	Net Expense	$	894		$	669
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, 2015, excluding accrued dividend equivalents:
		Officers &Other Key Employees			Directors			Weighted
								Average
								Fair Value
	Nonvested Shares Outstanding, January 1, 2015	223,876			23,220			$	24.4
	Granted	151,354			25,398			$	28.69
	Cancelled/Forfeited	(464	)		—			$	24.13
	Vested	—			(23,220	)		$	27.26
	Nonvested Shares Outstanding, March 31, 2015	374,766			25,398			$	26.13

DISCONTINUED_OPERATIONS_AND_AF1

DISCONTINUED OPERATIONS AND AFFILIATIONS (Tables)	3 Months Ended
	Mar. 31, 2015
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, 2015 and 2014, were (in thousands, except per share amounts):
		Three Months Ended
		March 31,
		2015			2014
	Loss Before Income Taxes:
	Sand Mining	$	(347	)	$	(380	)
	Fuel Oil	(66		)	(102		)
	Income Tax Benefits	137			169
	Loss from Discontinued Operations — Net	$	(276	)	$	(313	)
	Earnings (Loss) Per Common Share from
	Discontinued Operations — Net:
	Basic and Diluted	$	—		$	(0.01	)

COMMON_STOCK_Tables

COMMON STOCK (Tables)	3 Months Ended
	Mar. 31, 2015
Common Stock [Abstract]
Common stock shares issued and outstanding	The following shares were issued and outstanding:
		2015
	Beginning Balance, January 1 (See Note 1)	68,334,860
	New Issues During the Period:
	Dividend Reinvestment Plan	63,690
	Stock-Based Compensation Plan	25,398
	Ending Balance, March 31	68,423,948

SEGMENTS_OF_BUSINESS_Tables

SEGMENTS OF BUSINESS (Tables)	3 Months Ended
	Mar. 31, 2015
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,
		2015			2014
	Operating Revenues:
	Gas Utility Operations	$	267,658		$	210,545
	Energy Group:
	Wholesale Energy Operations	35,345			35,372
	Retail Gas and Other Operations	38,078			51,506
	Retail Electric Operations	29,777			40,393
	Subtotal Energy Group	103,200			127,271
	Energy Services:
	On-Site Energy Production	13,572			11,346
	Appliance Service Operations	2,357			2,654
	Subtotal Energy Services	15,929			14,000
	Corporate & Services	9,086			7,871
	Subtotal	395,873			359,687
	Intersegment Sales	(12,921		)	(9,486		)
	Total Operating Revenues	$	382,952		$	350,201
		Three Months Ended
		March 31,
		2015			2014
	Operating Income (Loss):
	Gas Utility Operations	$	73,189		$	63,440
	Energy Group:
	Wholesale Energy Operations	330			(1,655		)
	Retail Gas and Other Operations	3,087			1,968
	Retail Electric Operations	(182		)	(54		)
	Subtotal Energy Group	3,235			259
	Energy Services:
	On-Site Energy Production	(482		)	(1,260		)
	Appliance Service Operations	(52		)	(95		)
	Subtotal Energy Services	(534		)	(1,355		)
	Corporate and Services	481			166
	Total Operating Income	$	76,371		$	62,510
	Depreciation and Amortization:
	Gas Utility Operations	$	14,167		$	12,676
	Energy Group:
	Wholesale Energy Operations	32			40
	Retail Gas and Other Operations	20			22
	Subtotal Energy Group	52			62
	Energy Services:
	On-Site Energy Production	7,051			5,775
	Appliance Service Operations	74			67
	Subtotal Energy Services	7,125			5,842
	Corporate and Services	242			219
	Total Depreciation and Amortization	$	21,586		$	18,799
	Interest Charges:
	Gas Utility Operations	$	5,190		$	4,342
	Energy Group:
	Wholesale Energy Operations	242			121
	Retail Gas and Other Operations	73			126
	Subtotal Energy Group	315			247
	Energy Services:
	On-Site Energy Production	2,315			2,128
	Corporate and Services	2,988			1,850
	Subtotal	10,808			8,567
	Intersegment Borrowings	(2,207		)	(1,483		)
	Total Interest Charges	$	8,601		$	7,084
		Three Months Ended
		March 31,
		2015			2014
	Income Taxes:
	Gas Utility Operations	$	26,172		$	22,527
Energy Group:
Wholesale Energy Operations	867			(553		)
Retail Gas and Other Operations	1,576			936
Retail Electric Operations	(74		)	(22		)
Subtotal Energy Group	2,369			361
Energy Services:
On-Site Energy Production	(12,047		)	(11,025		)
Appliance Service Operations	(8		)	(23		)
Subtotal Energy Services	(12,055		)	(11,048		)
Corporate and Services	127			29
Total Income Taxes	$	16,613		$	11,869
Property Additions:
Gas Utility Operations	$	43,326		$	32,531
Energy Group:
Wholesale Energy Operations	4			2
Retail Gas and Other Operations	729			168
Subtotal Energy Group	733			170
Energy Services:
On-Site Energy Production	4,381			9,149
Appliance Service Operations	116			—
Subtotal Energy Services	4,497			9,149
Corporate and Services	1,064			778
Total Property Additions	$	49,620		$	42,628
	March 31, 2015			December 31, 2014
Identifiable Assets:
Gas Utility Operations	$	2,291,920		$	2,185,672
Energy Group:
Wholesale Energy Operations	294,484			366,119
Retail Gas and Other Operations	52,195			53,073
Retail Electric Operations	25,311			23,682
Subtotal Energy Group	371,990			442,874
Energy Services:
On-Site Energy Production	661,485			675,937
Appliance Service Operations	3,265			3,105
Subtotal Energy Services	664,750			679,042
Discontinued Operations	1,755			1,758
Corporate and Services	563,649			527,691
Intersegment Assets	(517,342		)	(487,612		)
Total Identifiable Assets	$	3,376,722		$	3,349,425

REGULATORY_ASSETS_REGULATORY_L1

REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)	3 Months Ended
	Mar. 31, 2015
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets	Regulatory Assets consisted of the following items (in thousands):
		March 31, 2015		December 31, 2014
	Environmental Remediation Costs:
	Expended - Net	$	28,057	$	29,540
	Liability for Future Expenditures	124,761		124,308
	Deferred Asset Retirement Obligation Costs	31,604		31,584
	Deferred Pension and Other Postretirement Benefit Costs	99,040		99,040
	Deferred Gas Costs - Net	20,291		32,202
	Societal Benefit Costs Receivable	—		385
	Deferred Interest Rate Contracts	8,330		7,325
	Energy Efficiency Tracker	1,782		11,247
	Pipeline Supplier Service Charges	5,025		5,441
	Pipeline Integrity Cost	3,439		3,431
	AFUDC - Equity Related Deferrals	10,987		10,781
	Other Regulatory Assets	1,693		1,876
	Total Regulatory Assets	$	335,009	$	357,160
Schedule of Regulatory Liabilities	Regulatory Liabilities consisted of the following items (in thousands):
		March 31, 2015		December 31, 2014
	Excess Plant Removal Costs	$	35,762	$	35,940
	Conservation Incentive Program Payable	21,825		4,700
	Societal Benefit Costs	8,939		—
	Other Regulatory Liabilities	—		1,259
	Total Regulatory Liabilities	$	66,526	$	41,899

PENSION_AND_OTHER_POSTRETIREME1

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	3 Months Ended
	Mar. 31, 2015
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
Schedule of defined benefit plans disclosures	For the three months ended March 31, 2015 and 2014, 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,
		2015			2014
	Service Cost	$	1,443		$	1,285
	Interest Cost	2,770			2,695
	Expected Return on Plan Assets	(3,699		)	(3,265		)
	Amortizations:
	Prior Service Cost	53			43
	Actuarial Loss	2,656			1,426
	Net Periodic Benefit Cost	3,223			2,184
	Capitalized Benefit Costs	(1,239		)	(854		)
	Total Net Periodic Benefit Expense	$	1,984		$	1,330
		Other Postretirement Benefits
		Three Months Ended
		March 31,
		2015			2014
	Service Cost	$	327		$	250
	Interest Cost	771			740
	Expected Return on Plan Assets	(748		)	(687		)
	Amortizations:
	Prior Service Cost	152			38
	Actuarial Loss	384			243
	Net Periodic Benefit Cost	886			584
	Capitalized Benefit Costs	(256		)	(209		)
	Total Net Periodic Benefit Expense	$	630		$	375

LINES_OF_CREDIT_Tables

LINES OF CREDIT (Tables)	3 Months Ended
	Mar. 31, 2015
Line of Credit Facility [Abstract]
Schedule of lines of credit	Credit facilities and available liquidity as of March 31, 2015 were as follows (in thousands):
	Company	Total Facility		Usage		Available Liquidity		Expiration Date
	SJG:
	Commercial Paper Program/Revolving Credit Facility	$	200,000	$	129,600	$	70,400	May-18
	Uncommitted Bank Lines	10,000		—		10,000		Aug-15
	Total SJG	210,000		129,600		80,400
	SJI:
	Revolving Credit Facility	400,000		156,400		243,600		February 2018 (A)
	Total SJI	400,000		156,400		243,600
	Total	$	610,000	$	286,000	$	324,000
	(A) Includes letters of credit outstanding in the amount of $13.6 million.

DERIVATIVE_INSTRUMENTS_Tables

DERIVATIVE INSTRUMENTS (Tables)	3 Months Ended
	Mar. 31, 2015
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, 2015 and December 31, 2014, are as follows (in thousands):
	Derivatives not designated as hedging instruments under GAAP	March 31, 2015						December 31, 2014
		Assets			Liabilities			Assets			Liabilities
	Energy related commodity contracts:
	Derivatives – Energy Related – Current	$	52,441		$	81,779		$	85,368		$	109,744
	Derivatives – Energy Related – Non-Current	15,402			24,522			13,905			19,926
	Interest rate contracts:
	Derivatives - Other	—			12,036			—			10,732
	Total derivatives not designated as hedging instruments under GAAP	67,843			118,337			99,273			140,402
	Total Derivatives	$	67,843		$	118,337		$	99,273		$	140,402
Offsetting assets and liabilities	As of March 31, 2015 and December 31, 2014, information related to these offsetting arrangements were as follows (in thousands):
	As of March 31, 2015
	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	$	67,843		$	—		$	67,843		$	(24,796	)	(A)	$	—	$	43,047
	Derivatives - Energy Related Liabilities	$	(106,301	)	$	—		$	(106,301	)	$	24,796		(B)	$	42,770	$	(38,735	)
	Derivatives - Other	$	(12,036	)	$	—		$	(12,036	)	$	—			$	—	$	(12,036	)
	As of December 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	$	99,273		$	—		$	99,273		$	(39,747	)	(A)	$	—	$	59,526
	Derivatives - Energy Related Liabilities	$	(129,670	)	$	—		$	(129,670	)	$	39,747		(B)	$	53,897	$	(36,026	)
	Derivatives - Other	$	(10,732	)	$	—		$	(10,732	)	$	—			$	—	$	(10,732	)
	(A) The balances at March 31, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets.
	(B) The balances at March 31, 2015 and December 31, 2014 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, 2015 and 2014 are as follows (in thousands):
		Three Months Ended
		March 31,
	Derivatives in Cash Flow Hedging Relationships under GAAP	2015			2014
	Interest Rate Contracts:
	Losses recognized in AOCL on effective portion	$	—		$	—
	Losses reclassified from AOCL into income (a)	$	(23	)	$	(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	2015			2014
	Losses on energy related commodity contracts (a)	$	(6,707	)	$	(28,601	)
	Losses on interest rate contracts (b)	(298		)	(214		)
	Total	$	(7,005	)	$	(28,815	)
	(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, 2015
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, 2015	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	15,245			$	9,816			$	5,429	$	—
	Derivatives – Energy Related Assets (B)	67,843				12,154				29,681		26,008
		$	83,088			$	21,970			$	35,110	$	26,008
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	106,301			$	37,798			$	25,184	$	43,319
	Derivatives – Other (C)	12,036				—				12,036		—
		$	118,337			$	37,798			$	37,220	$	43,319
	As of December 31, 2014	Total				Level 1				Level 2		Level 3
	Assets
	Available-for-Sale Securities (A)	$	8,922			$	5,952			$	2,970	$	—
	Derivatives – Energy Related Assets (B)	99,273				21,675				43,093		34,505
		$	108,195			$	27,627			$	46,063	$	34,505
	Liabilities
	Derivatives – Energy Related Liabilities (B)	$	129,670			$	49,009			$	40,548	$	40,113
	Derivatives – Other (C)	10,732				—				10,732		—
		$	140,402			$	49,009			$	51,280	$	40,113
	(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, 2015		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets	Liabilities
	Forward Contract - Natural Gas	$19,557	$38,607	Discounted Cash Flow	Forward price (per dt)	$(1.61) - $7.25 [$(0.28)]
	Forward Contract - Electric	$6,451	$4,712	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [56.75%]
					Fixed electric load profile (off-peak)	0.00% - 91.94% [43.25%]
	Type	Fair Value at December 31, 2014						Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
		Assets			Liabilities
	Forward Contract - Natural Gas	$	26,485		$	33,882		Discounted Cash Flow	Forward price (per dt)	$(2.04) - $7.83 [$(0.30)]
	Forward Contract - Electric	$	8,020		$	6,231		Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [55.97%]
									Fixed electric load profile (off-peak)	0.00% - 91.94% [44.03%]
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, 2015 and 2014, using significant unobservable inputs (Level 3), are as follows (in thousands):
		Three Months Ended				Three Months Ended March 31,2014
		31-Mar-15
	Balance at beginning of period	$	(5,608	)		$	8,095
	Other changes in fair value from continuing and new contracts, net	(16,438		)		(12,124		)
	Settlements	4,735				(942		)
	Balance at end of period	$	(17,311	)		$	(4,971	)

ACCUMULATED_OTHER_COMPREHENSIV1

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	3 Months Ended
	Mar. 31, 2015
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, 2015 (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, 2015 (a)	$	(27,663	)	$	(2,450	)	$	(75	)	$	(70	)	$	(30,258	)
	Other comprehensive income before reclassifications	—			—			92			—			92
	Amounts reclassified from AOCL (b)	—			8			(4		)	(95		)	(91		)
	Net current period other comprehensive income (loss)	—			8			88			(95		)	1
	Balance at March 31, 2015 (a)	$	(27,663	)	$	(2,442	)	$	13		$	(165	)	$	(30,257	)
	(a) For 2015, determined using a combined average statutory tax rate of 40%. For 2014, 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, 2015:
		Amounts Reclassified from AOCL (in thousands)				Affected Line Item in the Condensed Consolidated Statements of Income
		Three Months Ended
		31-Mar-15
	Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	23			Interest Charges
	Income Taxes	(15		)		Income Taxes (a)
		$	8
	Unrealized Loss on Available-for-Sale Securities	$	(7	)		Other Income
	Income Taxes	3				Income Taxes (a)
		$	(4	)
	Loss of Affiliated Companies	$	(153	)		Equity in Loss of Affiliated Companies
	Income Taxes	58				Income Taxes (a)
		$	(95	)
	Losses from reclassifications for the period net of tax	$	(91	)

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	0 Months Ended	3 Months Ended
	Feb. 26, 2015	Mar. 31, 2015	Mar. 31, 2014	Feb. 26, 2015	Feb. 25, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
Common stock, authorized (in shares)				120,000,000	60,000,000
Stockholders' Equity Note, Stock Split, Conversion Ratio	2
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales		$600,000	$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)		227,432				263,578

STOCKBASED_COMPENSATION_PLAN_D

STOCK-BASED COMPENSATION PLAN (Details) (USD $)	3 Months Ended		12 Months Ended	1 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014	Jan. 31, 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of options granted	0	0
Fair value per share (in dollars per share)	$26.13
Expected volatility, measurement period	3 years
Service period of shares (in years)	3 years
Cost	$985,000	$739,000
Capitalized	-91,000	-70,000
Net Expense	894,000	669,000
Unrecognized compensation cost of awards granted under the plan	6,800,000
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)	$24.40			24.4
Weighted average fair value nonvested shares-granted during the period (in dollars per share)	$28.69
Weighted average fair value nonvested shares-cancelled/forfeited during the period (in dollars per share)	$24.13
Weighted average fair value nonvested shares-vested during the period (in dollars per share)	$27.26
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$26.13
Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted	151,354	136,526
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 200%
Shares outstanding (in shares)	374,766		223,876
Cost	799,000	581,000
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)	223,876			223,876
Granted (in shares)	151,354	136,526
Cancelled/Forfeited (in shares)	-464
Vested (in shares)	0
Nonvested shares outstanding, ending balance (in shares)	374,766		223,876
Additional disclosures [Abstract]
Number of shares awarded during the period	0		0
Officers and Key Employees | Grant Date January 2013 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	49,514
Fair value per share (in dollars per share)	$22.19
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)	49,514
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$22.19
Officers and Key Employees | Grant Date January 2013 - EPS
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	49,514
Fair value per share (in dollars per share)	$25.59
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	49,514
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$25.59
Officers and Key Employees | Grant Date January 2014, TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	62,192
Fair value per share (in dollars per share)	$21.31
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)	62,192
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$21.31
Officers and Key Employees | Grant Date January 2014, EPS
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	62,192
Fair value per share (in dollars per share)	$27.22
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	62,192
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$27.22
Officers and Key Employees | Grant Date January 2015, TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	42,378
Fair value per share (in dollars per share)	$26.31
Expected volatility (in hundredths)	16.00%
Risk-free interest rate (in hundredths)	1.10%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	42,378
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$26.31
Officers and Key Employees | Grant Date January 2015, EPS, ROE, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	108,976
Fair value per share (in dollars per share)	$29.47
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	108,976
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$29.47
Director
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted	25,398	23,220
Vesting period of shares (in years)	12 months
Shares Vested, Directors (in hundredths)	100.00%
Shares outstanding (in shares)	25,398
Cost	186,000	158,000
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)	23,220			23,220
Granted (in shares)	25,398	23,220
Cancelled/Forfeited (in shares)	0
Vested (in shares)	-23,220
Nonvested shares outstanding, ending balance (in shares)	25,398
Additional disclosures [Abstract]
Fair value of shares issued	$700,000	$600,000
Director | Grant Date January 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	25,398
Fair value per share (in dollars per share)	$29.34
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	25,398
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$29.34
Minimum | Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted	0.00%
Maximum | Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted	200.00%
Stock Appreciation Rights (SARs)
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted	0	0
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Granted (in shares)	0	0
Restricted Stock | Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted				45,406
Vesting period of shares (in years)	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Payout Limit, Percentage	100.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Granted (in shares)				45,406

DISCONTINUED_OPERATIONS_AND_AF2

DISCONTINUED OPERATIONS AND AFFILIATIONS (Details) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Loss Before Income Taxes:
Income Tax Benefits	$137	$169
Loss from Discontinued Operations b Net	-276	-313
Earnings (Loss) Per Common Share from
Basic and Diluted (in dollars per share)	$0	($0.01)
Sand Mining
Loss Before Income Taxes:
Loss Before Income Taxes	-347	-380
Fuel Oil
Loss Before Income Taxes:
Loss Before Income Taxes	($66)	($102)

DISCONTINUED_OPERATIONS_AND_AF3

DISCONTINUED OPERATIONS AND AFFILIATIONS 2 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Affiliations [Abstract]
Investments in unconsolidated affiliates	$1.70	$2.90
Notes Receivable - affiliate	52.4		51.5
Due from Affiliate, Noncurrent, Secured By Property, Plant, And Equipment	39.4
Interest accrual on secured notes receivable (in hundredths)	7.50%
Due from Affiliate, Noncurrent, Unsecured	13
Net asset - included in investment in affiliates and other noncurrent liabilities	66.9
Combined equity contributions and the notes receivable - affiliate	$120.20
Energenic US LLC
Affiliations [Abstract]
Equity interest (in hundredths)	50.00%
Potato Creek, LLC (Potato Creek)
Affiliations [Abstract]
Equity interest (in hundredths)	30.00%

COMMON_STOCK_Details

COMMON STOCK (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Common Stock [Roll Forward]
Beginning balance (in shares)	68,334,860
New Issues During the Period:
Dividend Reinvestment Plan (in shares)	63,690
Stock-Based Compensation Plan (in shares)	25,398
Ending balance (in shares)	68,423,948
Par value of common stock (in dollars per share)	$1.25
Net excess over par value recorded in premium on common stock	$2,600,000
Incremental shares included in diluted EPS calculation (in shares)	220,762	154,448
Proceeds from sale of common stock	$1,857,000	$5,157,000

FINANCIAL_INSTRUMENTS_Details

FINANCIAL INSTRUMENTS (Details) (USD $)	12 Months Ended
	Dec. 31, 2011	Mar. 31, 2015	Dec. 31, 2014
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted investments held In escrow		$1,700,000	$1,700,000
Margin accounts with selected counterparties to support risk management activities		58,900,000	63,700,000
Investment in Affiliates		67,754,000	68,351,000
Notes Receivable - Affiliate		36,525,000	36,799,000
South Jersey Gas Company | Financing Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Long-term receivables, net of unamortized discount		14,900,000	15,000,000
Imputed interest on long term receivables		1,200,000	1,300,000
Energenic US LLC
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity interest (in hundredths)		50.00%
Contract term (in years)	20 years
Investment in Affiliates		15,100,000
Notes Receivable - Affiliate		$13,900,000

FINANCIAL_INSTRUMENTS_2_Detail

FINANCIAL INSTRUMENTS 2 (Details) (Derivatives Energy Related Assets, Supplier Concentration Risk, USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
Derivatives Energy Related Assets | Supplier Concentration Risk
Concentration Risk [Line Items]
Amount of derivatives - energy related assets with single retail counterparty	$11.60
Percentage of derivatives - energy related assets with a single retail counterparty (in hundredths)	17.30%

FINANCIAL_INSTRUMENTS_3_Detail

FINANCIAL INSTRUMENTS 3 (Details) (USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014	Dec. 31, 2010
Schedule of Equity Method Investments [Line Items]
Finance obligation to ACB Energy Partners LLC	$19,420,000	$19,659,000
Estimated fair value of long-term debt	1,068,900,000	1,058,500,000
Carrying amount of long-term debt	1,009,400,000
Energenic US LLC
Schedule of Equity Method Investments [Line Items]
Equity interest of Marina in Energenic (in hundredths)	50.00%
Marina Energy LLC | Energenic US LLC
Schedule of Equity Method Investments [Line Items]
Equity interest of Marina in Energenic (in hundredths)			50.00%
Other construction costs	$23,700,000	$23,700,000

SEGMENTS_OF_BUSINESS_Details

SEGMENTS OF BUSINESS (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Operating Revenues	$382,952	$350,201
Operating Income (Loss)	76,371	62,510
Depreciation and Amortization	21,586	18,799
Interest Charges	8,601	7,084
Income Taxes	16,613	11,869
Property Additions	49,620	42,628
Identifiable Assets	3,376,722		3,349,425
Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues	395,873	359,687
Interest Charges	10,808	8,567
Operating Segments | Gas Utility Operations
Segment Reporting Information [Line Items]
Operating Revenues	267,658	210,545
Operating Income (Loss)	73,189	63,440
Depreciation and Amortization	14,167	12,676
Interest Charges	5,190	4,342
Income Taxes	26,172	22,527
Property Additions	43,326	32,531
Identifiable Assets	2,291,920		2,185,672
Operating Segments | Energy Group
Segment Reporting Information [Line Items]
Operating Revenues	103,200	127,271
Operating Income (Loss)	3,235	259
Depreciation and Amortization	52	62
Interest Charges	315	247
Income Taxes	2,369	361
Property Additions	733	170
Identifiable Assets	371,990		442,874
Operating Segments | Energy Group | Wholesale Energy Operations
Segment Reporting Information [Line Items]
Operating Revenues	35,345	35,372
Operating Income (Loss)	330	-1,655
Depreciation and Amortization	32	40
Interest Charges	242	121
Income Taxes	867	-553
Property Additions	4	2
Identifiable Assets	294,484		366,119
Operating Segments | Energy Group | Retail Gas and Other Operations
Segment Reporting Information [Line Items]
Operating Revenues	38,078	51,506
Operating Income (Loss)	3,087	1,968
Depreciation and Amortization	20	22
Interest Charges	73	126
Income Taxes	1,576	936
Property Additions	729	168
Identifiable Assets	52,195		53,073
Operating Segments | Energy Group | Retail Electric Operations
Segment Reporting Information [Line Items]
Operating Revenues	29,777	40,393
Operating Income (Loss)	-182	-54
Income Taxes	-74	-22
Identifiable Assets	25,311		23,682
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Operating Revenues	15,929	14,000
Operating Income (Loss)	-534	-1,355
Depreciation and Amortization	7,125	5,842
Income Taxes	-12,055	-11,048
Property Additions	4,497	9,149
Identifiable Assets	664,750		679,042
Operating Segments | Energy Services | On-site Energy Production
Segment Reporting Information [Line Items]
Operating Revenues	13,572	11,346
Operating Income (Loss)	-482	-1,260
Depreciation and Amortization	7,051	5,775
Interest Charges	2,315	2,128
Income Taxes	-12,047	-11,025
Property Additions	4,381	9,149
Identifiable Assets	661,485		675,937
Operating Segments | Energy Services | Appliance Service Operations
Segment Reporting Information [Line Items]
Operating Revenues	2,357	2,654
Operating Income (Loss)	-52	-95
Depreciation and Amortization	74	67
Income Taxes	-8	-23
Property Additions	116	0
Identifiable Assets	3,265		3,105
Operating Segments | Corporate and Services
Segment Reporting Information [Line Items]
Operating Revenues	9,086	7,871
Operating Income (Loss)	481	166
Depreciation and Amortization	242	219
Interest Charges	2,988	1,850
Income Taxes	127	29
Property Additions	1,064	778
Identifiable Assets	563,649		527,691
Discontinued Operations
Segment Reporting Information [Line Items]
Identifiable Assets	1,755		1,758
Intersegment Elimination
Segment Reporting Information [Line Items]
Operating Revenues	-12,921	-9,486
Interest Charges	-2,207	-1,483
Identifiable Assets	($517,342)		($487,612)

RATES_AND_REGULATORY_ACTIONS_D

RATES AND REGULATORY ACTIONS (Details) (USD $)	0 Months Ended
In Millions, unless otherwise specified	Oct. 01, 2014	Sep. 30, 2014	Jan. 31, 2015
Schedule of Capitalization [Line Items]
Approved base rate increase	$20
Rate of return on base rate	7.10%
Return on common equity	9.75%
Depreciate rate	2.10%	2.40%
Accelerated Infrastructure Replacement Program
Schedule of Capitalization [Line Items]
Approved base rate increase	7.5
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Amount of regulatory costs approved, statewide			$56

REGULATORY_ASSETS_REGULATORY_L2

REGULATORY ASSETS & REGULATORY LIABILITIES (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Regulatory Assets [Line Items]
Total Regulatory Assets	$335,009	$357,160
Environmental Remediation Costs: Expended - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	28,057	29,540
Environmental Remediation Costs: Liability for Future Expenditures
Regulatory Assets [Line Items]
Total Regulatory Assets	124,761	124,308
Deferred Asset Retirement Obligation Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	31,604	31,584
Deferred Pension and Other Postretirement Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	99,040	99,040
Deferred Gas Costs - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	20,291	32,202
Societal Benefit Costs Receivable
Regulatory Assets [Line Items]
Total Regulatory Assets	0	385
Deferred Interest Rate Contracts
Regulatory Assets [Line Items]
Total Regulatory Assets	8,330	7,325
Energy Efficiency Tracker
Regulatory Assets [Line Items]
Total Regulatory Assets	1,782	11,247
Pipeline Supplier Service Charges
Regulatory Assets [Line Items]
Total Regulatory Assets	5,025	5,441
Pipeline Integrity Cost
Regulatory Assets [Line Items]
Total Regulatory Assets	3,439	3,431
AFUDC - Equity Related Deferrals
Regulatory Assets [Line Items]
Total Regulatory Assets	10,987	10,781
Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	$1,693	$1,876

REGULATORY_ASSETS_REGULATORY_L3

REGULATORY ASSETS & REGULATORY LIABILITIES 2 (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$66,526	$41,899
Excess Plant Removal Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	35,762	35,940
Conservation Incentive Program Payable
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	21,825	4,700
Societal Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	8,939	0
Other Regulatory Liablities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$0	$1,259

PENSION_AND_OTHER_POSTRETIREME2

PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) (USD $)	1 Months Ended	3 Months Ended		12 Months Ended
	Jan. 31, 2015	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Pension Benefits
Net periodic benefit cost [Abstract]
Service Cost		$1,443,000	$1,285,000
Interest Cost		2,770,000	2,695,000
Expected Return on Plan Assets		-3,699,000	-3,265,000
Amortizations:
Prior Service Cost		53,000	43,000
Actuarial Loss		2,656,000	1,426,000
Net Periodic Benefit Cost		3,223,000	2,184,000
Capitalized Benefit Costs		-1,239,000	-854,000
Total Net Periodic Benefit Expense		1,984,000	1,330,000
Contributions	15,000,000			0
Other Postretirement Benefits
Net periodic benefit cost [Abstract]
Service Cost		327,000	250,000
Interest Cost		771,000	740,000
Expected Return on Plan Assets		-748,000	-687,000
Amortizations:
Prior Service Cost		152,000	38,000
Actuarial Loss		384,000	243,000
Net Periodic Benefit Cost		886,000	584,000
Capitalized Benefit Costs		-256,000	-209,000
Total Net Periodic Benefit Expense		630,000	375,000
Defined benefit plan regulatory obligation to contribute to the plan during the period		3,600,000
Supplemental Employee Retirement Plans, Defined Benefit
Amortizations:
Estimated future contributions		$1,500,000

LINES_OF_CREDIT_Details

LINES OF CREDIT (Details) (USD $)	3 Months Ended
	Mar. 31, 2015		Mar. 31, 2014
Line of Credit Facility [Line Items]
Total Facility	$610,000,000
Usage	286,000,000
Available Liquidity	324,000,000
Letters of credit outstanding	13,600,000
Weighted average borrowing cost	0.88%		1.06%
Average borrowings outstanding during the period	274,100,000		332,200,000
Maximum amounts outstanding during the period	329,400,000		390,700,000
Financial covenant, ratio of indebtedness to consolidated total capitalization	0.65 to 1
Minimum
Line of Credit Facility [Line Items]
Financial covenant, ratio of indebtedness to consolidated total capitalization minimum	0.65
SJG Commercial Paper Program
Line of Credit Facility [Line Items]
Total Facility	200,000,000
Fixed maturities of notes, at maximum number of days (in days)	270 days
South Jersey Gas Company
Line of Credit Facility [Line Items]
Total Facility	210,000,000
Usage	129,600,000
Available Liquidity	80,400,000
South Jersey Gas Company | Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility	200,000,000
Usage	129,600,000
Available Liquidity	70,400,000
Expiration Date	May-18
South Jersey Gas Company | Uncommitted Bank Lines
Line of Credit Facility [Line Items]
Total Facility	10,000,000
Usage	0
Available Liquidity	10,000,000
Expiration Date	Aug-15
South Jersey Industries Inc
Line of Credit Facility [Line Items]
Total Facility	400,000,000
Usage	156,400,000
Available Liquidity	243,600,000
South Jersey Industries Inc | Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility	400,000,000	[1]
Usage	156,400,000	[1]
Available Liquidity	$243,600,000	[1]
Expiration Date	February 2018 (A)	[1]
[1]	Includes letters of credit outstanding in the amount of $13.6 million.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Details) (USD $)	1 Months Ended	3 Months Ended
	31-May-12	Mar. 31, 2015	Dec. 31, 2014
			sites
Guarantees [Abstract]
Liability recorded related to guarantees		$600,000
Maximum amount of obligation under guarantee contracts		4,200,000
Notes receivable - affiliate		15,921,000	14,657,000
Collective bargaining agreements [Abstract]
Percentage of personnel represented by collective bargaining agreements (in hundredths)		45.00%
Number of unions (in unions)		2
Letter of credit provided		610,000,000
Pending litigation [Abstract]
Estimated litigation liability		3,200,000	2,900,000
Environmental remediation costs [Abstract]
Number of sites for environmental cleanup (in number of sites)			12
Standby Letter of Credit
Collective bargaining agreements [Abstract]
Letter of credit provided		13,600,000
Letter of Credit, Separate Facility
Collective bargaining agreements [Abstract]
Letter of credit provided		87,600,000
Energenic
Guarantees [Abstract]
Equity interest (in hundredths)		50.00%
Energenic | UMM Energy Partners, LLC
Guarantees [Abstract]
Contract term (in years)	30 years
Energenic | UMM Energy Partners, LLC | Maximum
Guarantees [Abstract]
Annual obligations under the agreement		2,400,000
LVE Energy Partners
Guarantees [Abstract]
Notes receivable - affiliate		8,600,000
Parental Guarantee
Guarantees [Abstract]
Guaranteed amount		$7,200,000

DERIVATIVE_INSTRUMENTS_Details

DERIVATIVE INSTRUMENTS (Details)	Mar. 31, 2015
	dts
Basis and Index Related Purchase and Sales Contracts
Derivative [Line Items]
Outstanding derivative contracts notional amount	315,300,000
Natural Gas (in MMdts) | Derivative Transaction Type, Purchase
Derivative [Line Items]
Outstanding derivative contracts notional amount	55,900,000
Natural Gas (in MMdts) | Derivative Transaction Type, Sale
Derivative [Line Items]
Outstanding derivative contracts notional amount	45,700,000
Electricity (in MMmwh) | Derivative Transaction Type, Purchase
Derivative [Line Items]
Outstanding derivative contracts notional amount	2,700,000
Electricity (in MMmwh) | Derivative Transaction Type, Sale
Derivative [Line Items]
Outstanding derivative contracts notional amount	2,700,000

DERIVATIVE_INSTRUMENTS_2_Detai

DERIVATIVE INSTRUMENTS 2 (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	$67,843	$99,273
Fair value Derivative Liabilities	118,337	140,402
Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	67,843	99,273
Fair value Derivative Liabilities	118,337	140,402
Commodity Contract | Not Designated as Hedging Instrument | Derivatives-Energy Related-Current
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	52,441	85,368
Fair value Derivative Liabilities	81,779	109,744
Commodity Contract | Not Designated as Hedging Instrument | Derivatives-Energy Related-NonCurrent
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	15,402	13,905
Fair value Derivative Liabilities	24,522	19,926
Interest Rate Contract | Not Designated as Hedging Instrument | Derivatives-Other
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$12,036	$10,732

DERIVATIVE_INSTRUMENTS_3_Detai

DERIVATIVE INSTRUMENTS 3 (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
Commodity Contract
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	$67,843		$99,273
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	67,843		99,273
Gross amounts not offset in the balance sheet, Financial Instruments	-24,796	[1]	-39,747	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		0
Net amount	43,047		59,526
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	-106,301		-129,670
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-106,301		-129,670
Gross amounts not offset in the balance sheet, Financial Instruments	24,796	[2]	39,747	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	42,770		53,897
Net amount	-38,735		-36,026
Interest Rate Contract
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	-12,036		-10,732
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	-12,036		-10,732
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	($12,036)		($10,732)
[1]	The balances at MarchB 31, 2015 and DecemberB 31, 2014 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at MarchB 31, 2015 and DecemberB 31, 2014 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, 2015		Mar. 31, 2014
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$0		$0
Losses reclassified from AOCL into income	-23,000	[1]	-112,000	[1]
Gains (losses) recognized in income on ineffective portion	0	[1]	0	[1]
Total	-7,005,000		-28,815,000
Net realized gains (losses), derivative instruments, energy-related contracts	-2,600,000		2,400,000
Fair value derivative instruments with credit-risk-related features	36,300,000
Additional collateral, aggregate fair value	30,200,000
Not Designated as Hedging Instrument
Interest Rate Contracts:
Losses on energy related commodity contracts	-6,707,000	[2]	-28,601,000	[2]
Losses on interest rate contracts	($298,000)	[1]	($214,000)	[1]
[1]	Included in Interest Charges
[2]	Included in Operating Revenues - Non Utility

FAIR_VALUE_OF_FINANCIAL_ASSETS2

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period	($5,608)		$8,095
Other changes in fair value from continuing and new contracts, net	-16,438		-12,124
Settlements	4,735		-942
Balance at end of period	-17,311		-4,971
Fair Value, Measurements, Recurring
Assets
Available-for-Sale Securities	15,245	[1]		8,922	[1]
Derivatives - Energy Related Assets	67,843	[2]		99,273	[2]
Total Assets	83,088			108,195
Liabilities
Derivatives - Energy Related Liabilities	106,301	[2]		129,670	[2]
Derivatives - Other	12,036	[3]		10,732	[3]
Total Liabilities	118,337			140,402
Fair Value, Measurements, Recurring | Level 1
Assets
Available-for-Sale Securities	9,816	[1]		5,952	[1]
Derivatives - Energy Related Assets	12,154	[2]		21,675	[2]
Total Assets	21,970			27,627
Liabilities
Derivatives - Energy Related Liabilities	37,798	[2]		49,009	[2]
Derivatives - Other	0	[3]		0	[3]
Total Liabilities	37,798			49,009
Fair Value, Measurements, Recurring | Level 2
Assets
Available-for-Sale Securities	5,429	[1]		2,970	[1]
Derivatives - Energy Related Assets	29,681	[2]		43,093	[2]
Total Assets	35,110			46,063
Liabilities
Derivatives - Energy Related Liabilities	25,184	[2]		40,548	[2]
Derivatives - Other	12,036	[3]		10,732	[3]
Total Liabilities	37,220			51,280
Fair Value, Measurements, Recurring | Level 3
Assets
Available-for-Sale Securities	0	[1]		0	[1]
Derivatives - Energy Related Assets	26,008	[2]		34,505	[2]
Total Assets	26,008			34,505
Liabilities
Derivatives - Energy Related Liabilities	43,319	[2]		40,113	[2]
Derivatives - Other	0	[3]		0	[3]
Total Liabilities	$43,319			$40,113
[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, Fair Value, Inputs, Level 3, USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	$19,557	$26,485
Liabilities	38,607	33,882
Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	6,451	8,020
Liabilities	$4,712	$6,231
Minimum | Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	-1.61	-2.04
Maximum | Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	7.25	7.83
Weighted Average | Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	-0.28	-0.3
On-Peak | Minimum | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	8.06%	8.06%
On-Peak | Maximum | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	100.00%	100.00%
On-Peak | Weighted Average | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	56.75%	55.97%
Off-Peak | Minimum | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	0.00%	0.00%
Off-Peak | Maximum | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	91.94%	91.94%
Off-Peak | Weighted Average | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	43.25%	44.03%

ACCUMULATED_OTHER_COMPREHENSIV2

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	($30,258)	[1]
Other comprehensive income before reclassifications	92
Amounts reclassified from AOCL	-91	[2]
Other Comprehensive Income - Net of Tax	1	[3]	110	[3]
Ending balance	-30,257	[1]
Combined statutory tax rate	40.00%		41.00%
Postretirement Liability Adjustment
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	-27,663	[1]
Other comprehensive income before reclassifications	0
Amounts reclassified from AOCL	0	[2]
Other Comprehensive Income - Net of Tax	0
Ending balance	-27,663	[1]
Unrealized Gain (Loss) on Derivatives-Other
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	-2,450	[1]
Other comprehensive income before reclassifications	0
Amounts reclassified from AOCL	8	[2]
Other Comprehensive Income - Net of Tax	8
Ending balance	-2,442	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	-75	[1]
Other comprehensive income before reclassifications	92
Amounts reclassified from AOCL	-4	[2]
Other Comprehensive Income - Net of Tax	88
Ending balance	13	[1]
Other Comprehensive Income (Loss) of Affiliated Companies
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	-70	[1]
Other comprehensive income before reclassifications	0
Amounts reclassified from AOCL	-95	[2]
Other Comprehensive Income - Net of Tax	-95
Ending balance	($165)	[1]
[1]	For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.
[2]	See table below.
[3]	.

ACCUMULATED_OTHER_COMPREHENSIV3

ACCUMULATED OTHER COMPREHENSIVE LOSS 2 (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	$8,601		$7,084
Nonoperating Income (Expense)	-2,241		-2,368
Equity in Loss of Affiliated Companies	-455		-2,286
Income Taxes	16,613		11,869
(Loss) Income from Continuing Operations	-53,853		-48,211
Reclassification out of Accumulated Other Comprehensive Income
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
(Loss) Income from Continuing Operations	-91
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Gain (Loss) on Derivatives-Other
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	23
Income Taxes	-15	[1]
(Loss) Income from Continuing Operations	8
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Loss on Available-for-Sale Securities
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Nonoperating Income (Expense)	-7
Income Taxes	3	[1]
(Loss) Income from Continuing Operations	-4
Reclassification out of Accumulated Other Comprehensive Income | Other Comprehensive Income (Loss) of Affiliated Companies
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Equity in Loss of Affiliated Companies	-153
Income Taxes	58	[1]
(Loss) Income from Continuing Operations	($95)
[1]	For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.