South Jersey Industries (SJIIU) 10-Q5 Nov 152015 Q3 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
Document and Entity Information - shares	Sep. 30, 2015	Nov. 02, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	SOUTH JERSEY INDUSTRIES INC
Entity Central Index Key	91,928
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		69,294,447

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015USD ($)$ / sharesshares	Sep. 30, 2014USD ($)$ / sharesshares	Sep. 30, 2015USD ($)$ / sharesshares	Sep. 30, 2014USD ($)$ / sharesshares
Operating Revenues:
Utility	$ 57,507	$ 60,756	$ 399,332	$ 339,988
Nonutility	83,555	61,671	302,393	265,911
Total Operating Revenues	141,062	122,427	701,725	605,899
Cost of Sales - (Excluding depreciation)
- Utility	21,808	23,205	191,683	150,905
- Nonutility	77,316	52,868	240,093	232,253
Operations	33,150	29,939	108,813	99,941
Maintenance	4,188	3,275	12,114	9,715
Depreciation	18,422	16,057	52,671	46,543
Energy and Other Taxes	1,231	1,196	4,693	4,390
Total Operating Expenses	156,115	126,540	610,067	543,747
Operating Loss	(15,053)	(4,113)	91,658	62,152
Other Income and Expense	2,241	3,419	7,522	9,972
Interest Charges	(8,107)	(6,768)	(24,182)	(20,698)
Loss Before Income Taxes	(20,919)	(7,462)	74,998	51,426
Income Taxes	10,968	8,325	(2,366)	5,966
Equity in Loss of Affiliated Companies	(2,581)	(5,139)	(17,970)	(3,756)
Loss from Continuing Operations	(12,532)	(4,276)	54,662	53,636
Loss from Discontinued Operations - (Net of tax benefit)	(91)	(120)	(441)	(513)
Net Loss	$ (12,623)	$ (4,396)	$ 54,221	$ 53,123
Basic Earnings Per Common Share:
Continuing Operations (in dollars per share) \| $ / shares	$ (0.18)	$ (0.07)	$ 0.80	$ 0.81
Discontinued Operations (in dollars per share) \| $ / shares	0	0	(0.01)	0
Basic Earnings Per Common Share (in dollars per share) \| $ / shares	$ (0.18)	$ (0.07)	$ 0.79	$ 0.81
Average Shares of Common Stock Outstanding - Basic (in shares) \| shares	68,607	66,332	68,491	65,932
Diluted Earnings Per Common Share:
Continuing Operations (in dollars per share) \| $ / shares	$ (0.18)	$ (0.07)	$ 0.80	$ 0.81
Discontinued Operations (in dollars per share) \| $ / shares	0	0	(0.01)	0
Diluted Earnings Per Common Share (in dollars per share) \| $ / shares	$ (0.18)	$ (0.07)	$ 0.79	$ 0.81
Average Shares of Common Stock Outstanding - Diluted (in shares) \| shares	68,607	66,332	68,689	66,082
Dividends Declared Per Common Share (in dollars per share) \| $ / shares	$ 0.25	$ 0.24	$ 0.75	$ 0.71

CONDENSED CONSOLIDATED STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Statement of Comprehensive Income [Abstract]
Net Loss		$ (12,623)	$ (4,396)	$ 54,221	$ 53,123
Other Comprehensive Loss, Net of Tax:
Unrealized Loss on Available-for-Sale Securities	[1]	(177)	(613)	(153)	(397)
Unrealized Gain on Derivatives - Other	[1]	52	66	171	198
Other Comprehensive (Loss) Income of Affiliated Companies	[1]	(96)	63	(132)	(37)
Other Comprehensive Loss - Net of Tax	[1]	(221)	(484)	(114)	(236)
Comprehensive Loss		$ (12,844)	$ (4,880)	$ 54,107	$ 52,887

[1]	For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.

CONDENSED CONSOLIDATED STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Statement of Comprehensive Income [Abstract]
Combined statutory tax rate	40.00%	41.00%	40.00%	41.00%

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Statement of Cash Flows [Abstract]
Net Cash Provided by Operating Activities	$ 151,886	$ 109,042
Cash Flows from Investing Activities:
Capital Expenditures	(234,550)	(203,918)
Purchase of Available for Sale Securities	(6,059)	0
Net Proceeds from Sale of (Purchase of) Restricted Investments in Margin Account	22,947	(4,815)
Net Sale of Restricted Investments from Escrowed Loan Proceeds	101	0
Investment in Long-Term Receivables	(13,784)	(4,881)
Proceeds from Long-Term Receivables	6,556	5,075
Notes Receivable	(9,919)	0
Purchase of Company-Owned Life Insurance	(1,764)	(1,172)
Investment in Affiliate	(6,099)	0
Advances on Notes Receivable - Affiliate	(2,163)	(3,472)
Repayment of Notes Receivable - Affiliate	3,835	4,761
Net Cash Used in Investing Activities	(240,899)	(208,422)
Cash Flows from Financing Activities:
Net Borrowings from (Repayments of) Short-Term Credit Facilities	105,700	(204,500)
Proceeds from Issuance of Long-Term Debt	80,000	329,000
Principal Repayments of Long-Term Debt	(74,100)	(21,000)
Payments for Issuance of Long-Term Debt	(8)	(2,159)
Dividends on Common Stock	(34,397)	(31,121)
Proceeds from Sale of Common Stock	9,705	29,125
Net Cash Provided by Financing Activities	86,900	99,345
Net Decrease in Cash and Cash Equivalents	(2,113)	(35)
Cash and Cash Equivalents at Beginning of Period	4,171	3,818
Cash and Cash Equivalents at End of Period	$ 2,058	$ 3,783

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Property, Plant and Equipment:
Utility Plant, at original cost	$ 2,151,526	$ 2,002,966
Accumulated Depreciation	(431,327)	(413,597)
Nonutility Property and Equipment, at cost	691,565	622,079
Accumulated Depreciation	(100,218)	(77,345)
Property, Plant and Equipment - Net	2,311,546	2,134,103
Investments:
Available-for-Sale Securities	14,371	8,922
Restricted	43,365	65,451
Investment in Affiliates	53,237	68,351
Total Investments	110,973	142,724
Current Assets:
Cash and Cash Equivalents	2,058	4,171
Accounts Receivable	213,113	251,892
Unbilled Revenues	22,035	62,608
Provision for Uncollectibles	(10,320)	(7,910)
Notes Receivable	9,919	0
Notes Receivable - Affiliate	13,765	14,657
Natural Gas in Storage, average cost	53,263	63,246
Materials and Supplies, average cost	1,937	2,125
Deferred Income Taxes - Net	67,421	57,748
Prepaid Taxes	17,303	14,106
Derivatives - Energy Related Assets	60,536	85,368
Other Prepayments and Current Assets	27,904	18,686
Total Current Assets	478,934	566,697
Regulatory and Other Noncurrent Assets:
Regulatory Assets	339,192	357,160
Derivatives - Energy Related Assets	17,138	13,905
Unamortized Debt Issuance Costs	8,813	9,795
Notes Receivable - Affiliate	36,019	36,799
Contract Receivables	26,081	19,236
Notes Receivable	7,882	7,882
Other	62,930	61,124
Total Regulatory and Other Noncurrent Assets	498,055	505,901
Total Assets	3,399,508	3,349,425
Equity:
Common Stock	85,909	85,418
Premium on Common Stock	449,792	438,384
Treasury Stock (at par)	(290)	(330)
Accumulated Other Comprehensive Loss	(30,372)	(30,258)
Retained Earnings	441,789	439,218
Total Equity	946,828	932,432
Long-Term Debt	937,391	859,491
Total Capitalization	1,884,219	1,791,923
Current Liabilities:
Notes Payable	351,400	245,700
Current Portion of Long-Term Debt	77,909	149,909
Accounts Payable	189,122	272,998
Customer Deposits and Credit Balances	20,886	17,958
Environmental Remediation Costs	46,307	30,430
Taxes Accrued	2,353	2,328
Derivatives - Energy Related Liabilities	86,793	109,744
Dividends Payable	17,268	0
Interest Accrued	6,121	7,088
Pension Benefits	1,515	1,550
Other Current Liabilities	7,287	12,480
Total Current Liabilities	806,961	850,185
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	350,062	344,520
Investment Tax Credits	37	149
Pension and Other Postretirement Benefits	103,046	115,373
Environmental Remediation Costs	82,575	97,742
Asset Retirement Obligations	43,055	42,502
Derivatives - Energy Related Liabilities	23,490	19,926
Derivatives - Other	11,518	10,732
Regulatory Liabilities	62,461	41,899
Finance Obligation	18,912	19,659
Other	13,172	14,815
Total Deferred Credits and Other Noncurrent Liabilities	$ 708,328	$ 707,317
Commitments and Contingencies
Total Capitalization and Liabilities	$ 3,399,508	$ 3,349,425

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	Sep. 30, 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 (Midstream) 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 was to permit a two -for-one split of all the issued shares of SJI's common stock, 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 adjusted for all periods presented 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 $0.2 million for each of the three months ended September 30, 2015 and 2014 , and $1.0 million and $0.8 million for the nine months ended September 30, 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 nine months ended September 30, 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 nine months ended September 30, 2015 or 2014 . As of both September 30, 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 September 30, 2015 and December 31, 2014 , SJI held 231,749 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 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, 2017. 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, including interim periods within those annual periods, beginning after December 15, 2015, 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, including interim periods within those annual periods, beginning after December 15, 2015. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. Also in April 2015, the FASB issued ASU 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40) . This ASU provides guidance to customers (a) in determining whether a cloud computing arrangement includes a software license, and (b) on how the arrangement should be accounted for, depending on whether or not it includes a software license. The amended guidance is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory . This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, 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 2015, the FASB issued ASU 2015-13, Derivatives and Hedging (Topic 815): Application of the Normal Purchases and Normal Sales Scope Exception to Certain Electricity Contracts within Nodal Energy Markets . This ASU clarifies that for a contract involving the purchase or sale of electricity on a forward basis, companies have the option to elect the normal purchases and normal sales scope exception. Since such contracts meet the physical delivery criterion when the delivery location is within a nodal energy market (i.e., an interconnected electricity grid operated by an independent system operator with established price points at each node or hub location), the ASU notes that it does not constitute net settlement and, consequently, does not cause such a contract to fail to meet the physical delivery criterion. The standard is effective immediately and should be applied prospectively to qualifying contracts existing on August 10, 2015, the date the ASU was issued. The adoption of this standard did not have an impact on the Company's financial statement results. In August 2015, the FASB issued ASU 2015-15, Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements. This ASU states that, given the absence of authoritative guidance for debt issuance costs related to line-of-credit arrangements within ASU 2015-03 (defined above), the SEC staff would not object to an entity deferring and presenting such costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of credit arrangement. The adoption of this standard did not have an impact on the Company's financial statement results.

STOCK-BASED COMPENSATION PLAN

STOCK-BASED COMPENSATION PLAN	9 Months Ended
STOCK-BASED COMPENSATION PLAN	Sep. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
STOCK-BASED COMPENSATION PLAN	STOCK-BASED COMPENSATION PLAN: On April 30, 2015, the shareholders of SJI approved the adoption of the Company's 2015 Omnibus Equity Compensation Plan (Plan), replacing the Amended and Restated 1997 Stock-Based Compensation Plan that had terminated on January 26, 2015. Under the Plan, shares may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. No options were granted or outstanding during the nine months ended September 30, 2015 and 2014 . No stock appreciation rights have been issued under the plans. During the nine months ended September 30, 2015 and 2014 , SJI granted 158,929 and 136,906 restricted shares, respectively, to Officers and other key employees under the plans. 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 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. Vesting of time-based grants is contingent upon SJI achieving a return on equity (ROE) of at least 7% during the initial year of the grant and meeting the service requirement. Provided that the 7% ROE requirement is met in the initial year, payout is solely contingent upon the service requirement being met in years two and three of the grant. In 2015, Officers and other key employees were granted 47,678 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 nine months ended September 30, 2015 and 2014 , SJI granted 26,338 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 September 30, 2015 and the assumptions used to estimate the fair value of the awards: Grants Shares Outstanding Fair Value Per Share Expected Volatility Risk-Free Interest Rate Officers & Key Employees - 2013 - TSR 45,622 $ 22.19 21.1 % 0.40 % 2013 - EPS 45,622 $ 25.59 N/A N/A 2014 - TSR 51,349 $ 21.31 20.0 % 0.80 % 2014 - EPS 51,349 $ 27.22 N/A N/A 2015 - TSR 34,574 $ 26.31 16.0 % 1.10 % 2015 - EPS, ROE, Time 88,919 $ 29.47 N/A N/A Directors - 2015 26,338 $ 29.21 N/A N/A Expected volatility is based on the actual volatility of SJI’s share price over the preceding three -year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three -year term of the Officers’ and other key employees’ restricted shares. As notional dividend equivalents are credited to the holders during the three -year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant. The following table summarizes the total stock-based compensation cost for the three and nine months ended September 30, 2015 and 2014 (in thousands): Three Months Ended Nine Months Ended 2015 2014 2015 2014 Officers & Key Employees $ 654 $ 584 $ 1,964 $ 1,751 Directors 205 159 577 475 Total Cost 859 743 2,541 2,226 Capitalized (92 ) (70 ) (270 ) (210 ) Net Expense $ 767 $ 673 $ 2,271 $ 2,016 As of September 30, 2015 , there was $3.8 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 1.8 years. The following table summarizes information regarding restricted stock award activity during the nine months ended September 30, 2015 , excluding accrued dividend equivalents: Officers &Other Key Employees Directors Weighted Average Fair Value Nonvested Shares Outstanding, January 1, 2015 223,876 23,220 $ 24.40 Granted 158,929 26,338 $ 28.67 Cancelled/Forfeited (65,370 ) — $ 26.56 Vested — (23,220 ) $ 27.26 Nonvested Shares Outstanding, September 30, 2015 317,435 26,338 $ 26.10 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 nine months ended September 30, 2015 and 2014 , SJI granted 26,338 and 23,220 shares to its Directors at a market value of $0.8 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 AFF

DISCONTINUED OPERATIONS AND AFFILIATIONS	9 Months Ended
DISCONTINUED OPERATIONS AND AFFILIATIONS	Sep. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
DISCONTINUED OPERATIONS AND AFFILIATIONS	DISCONTINUED OPERATIONS AND AFFILATIONS: Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (EMI), an SJI subsidiary, which previously operated a fuel oil business. Morie is the former sand mining and processing subsidiary of EMI. EMI sold the common stock of Morie in 1996. SJI conducts tests annually to estimate the environmental remediation costs for these properties. Summarized operating results of the discontinued operations for the three and nine months ended September 30 , 2015 and 2014, were (in thousands, except per share amounts): Three Months Ended Nine Months Ended 2015 2014 2015 2014 Loss Before Income Taxes: Sand Mining $ (17 ) $ (79 ) $ (381 ) $ (562 ) Fuel Oil (123 ) (105 ) (286 ) (227 ) Income Tax Benefits 49 64 226 276 Loss from Discontinued Operations — Net $ (91 ) $ (120 ) $ (441 ) $ (513 ) 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. PennEast Pipeline Company, LLC (PennEast) - Midstream has a 20% investment in PennEast, which is planning to construct an approximately 100 -mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, with a target completion of late 2017. During the first nine months of 2015 and 2014, the Company received net repayments from unconsolidated affiliates of $4.4 million and $1.3 million , respectively. As of September 30, 2015 and December 31, 2014 , the outstanding balance of Notes Receivable – Affiliate was $49.8 million and $51.5 million , respectively. As of September 30, 2015 , approximately $38.9 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 , and the remaining $10.9 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 September 30, 2015 , the Company had a net asset of approximately $52.4 million included in Investment in Affiliates and Other Noncurrent Liabilities on the condensed consolidated balance sheets related to equity method investees, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of September 30, 2015 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $103.0 million plus the guarantees discussed in Note 11. The following table presents summarized income statement information of the total balances for Energenic (of which SJI has only a 50% equity interest) accounted for under the equity method (in thousands): Three Months Ended Nine Months Ended 2015 2014 2015 2014 Revenues $ 18,183 $ 27,160 $ 63,812 $ 83,380 Cost of Sales $ 5,048 $ 5,390 $ 16,452 $ 20,588 Loss from continuing operations $ (4,984 ) $ (4,154 ) $ (42,367 ) $ (4,139 ) Net Loss $ (4,984 ) $ (4,154 ) $ (42,367 ) $ (4,139 )

COMMON STOCK

COMMON STOCK	9 Months Ended
COMMON STOCK	Sep. 30, 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 366,262 Stock-Based Compensation Plan 26,338 Ending Balance, September 30 68,727,460 The par value ( $1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $11.4 million was recorded in Premium on Common Stock. EARNINGS PER COMMON SHARE (EPS) - Basic EPS is based on the weighted-average number of common shares outstanding. The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 198,222 and 150,592 for the nine months ended September 30, 2015 and 2014, respectively. For the three months ended September 30, 2015 and 2014, incremental shares of 187,758 and 148,664 , respectively, were not included in the denominator for the diluted EPS calculation because they would have an antidilutive effect on EPS. These shares relate to SJI's restricted stock as discussed in Note 2. DIVIDEND REINVESTMENT PLAN (DRP) - The Company offers a DRP which allows participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases. Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $9.7 million and $29.1 million of equity capital through the DRP during the nine months ended September 30, 2015 and 2014 , respectively.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	9 Months Ended
FINANCIAL INSTRUMENTS	Sep. 30, 2015
Financial Instruments, Owned, at Fair Value [Abstract]
FINANCIAL INSTRUMENTS	FINANCIAL INSTRUMENTS: RESTRICTED INVESTMENTS — Marina is required to maintain escrow accounts related to ongoing capital projects as well as unused loan proceeds pending approval of construction expenditures. As of September 30, 2015 and December 31, 2014 , the escrowed funds, including interest earned, totaled $2.6 million and 1.7 million , respectively. The Company maintains margin accounts with selected counterparties to support its risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy-related contracts with the respective counterparties decrease. As of September 30, 2015 and December 31, 2014 , the balances in these accounts totaled $40.8 million and $63.7 million , respectively. The carrying amounts of the Restricted Investments approximate their fair values at September 30, 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. However, the Energenic subsidiaries have not been able to secure a permanent or long-term energy services agreement with the new owner. As a result, management of the Company and Energenic have evaluated the carrying value of the investment in this project and a related note receivable. Based on the current situation, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge is included in Equity in Loss of Affiliated Companies for the nine months ended September 30, 2015 on the condensed consolidated statements of income. 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 this estimate. As of September 30, 2015 , the Company, through its investment in Energenic, had a remaining net asset of approximately $2.0 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 Energenic, 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 and will evaluate the carrying value of the investment and the note receivable as future events occur. NOTE RECEIVABLE - In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The Note bears interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. SJG holds a first lien security interest on land in Atlantic City as collateral against this Note. The carrying amount of this receivable approximates its fair value at September 30, 2015 , which would be included in Level 2 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities). LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources. The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest. The carrying amounts of such loans were $13.3 million and $15.0 million as of September 30, 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 $1.3 million as of both September 30, 2015 and December 31, 2014 . The annualized amortization to interest is not material to the Company’s condensed consolidated financial statements. The carrying amounts of these receivables approximate their fair value at September 30, 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 September 30, 2015 , approximately $8.8 million , or 11.4% , 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 September 30, 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 $18.9 million and $19.7 million , net of amortization, within Finance Obligation on the condensed consolidated balance sheets at September 30, 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 September 30, 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 September 30, 2015 and December 31, 2014 , were $1,072.3 million and $1,058.5 million , respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of September 30, 2015 and December 31, 2014 , were $1,015.3 million and $1,009.4 million , respectively.

SEGMENTS OF BUSINESS

SEGMENTS OF BUSINESS	9 Months Ended
SEGMENTS OF BUSINESS	Sep. 30, 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. • The activities of Midstream are a part of the Corporate & Services segment. SJI groups its nonutility 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 Nine Months Ended 2015 2014 2015 2014 Operating Revenues: Gas Utility Operations $ 58,634 $ 60,952 $ 402,104 $ 340,656 Energy Group: Wholesale Energy Operations 9,352 (3,538 ) 77,973 28,898 Retail Gas and Other Operations 11,757 18,900 67,900 95,281 Retail Electric Operations 44,240 29,961 110,203 98,233 Subtotal Energy Group 65,349 45,323 256,076 222,412 Energy Services: On-Site Energy Production 18,898 16,453 47,606 42,196 Appliance Service Operations 2,290 2,319 7,346 7,610 Subtotal Energy Services 21,188 18,772 54,952 49,806 Corporate & Services 6,925 7,001 23,776 21,324 Subtotal 152,096 132,048 736,908 634,198 Intersegment Sales (11,034 ) (9,621 ) (35,183 ) (28,299 ) Total Operating Revenues $ 141,062 $ 122,427 $ 701,725 $ 605,899 Three Months Ended Nine Months Ended 2015 2014 2015 2014 Operating (Loss) Income: Gas Utility Operations $ (2,501 ) $ 3,368 $ 82,649 $ 75,813 Energy Group: Wholesale Energy Operations (11,813 ) (10,314 ) 3,675 (20,437 ) Retail Gas and Other Operations (4,821 ) (390 ) (1,581 ) 1,387 Retail Electric Operations 1,034 373 1,026 (521 ) Subtotal Energy Group (15,600 ) (10,331 ) 3,120 (19,571 ) Energy Services: On-Site Energy Production 2,265 2,171 3,960 4,547 Appliance Service Operations 216 60 411 322 Subtotal Energy Services 2,481 2,231 4,371 4,869 Corporate and Services 567 619 1,518 1,041 Total Operating (Loss) Income $ (15,053 ) $ (4,113 ) $ 91,658 $ 62,152 Depreciation and Amortization: Gas Utility Operations $ 14,911 $ 12,942 $ 43,317 $ 38,375 Energy Group: Wholesale Energy Operations 191 37 238 123 Retail Gas and Other Operations 39 19 79 61 Subtotal Energy Group 230 56 317 184 Energy Services: On-Site Energy Production 7,650 6,540 22,158 18,480 Appliance Service Operations 85 68 232 202 Subtotal Energy Services 7,735 6,608 22,390 18,682 Corporate and Services 261 (41 ) 961 413 Total Depreciation and Amortization $ 23,137 $ 19,565 $ 66,985 $ 57,654 Interest Charges: Gas Utility Operations $ 4,809 $ 4,046 $ 15,112 $ 12,680 Energy Group: Wholesale Energy Operations 150 74 280 190 Retail Gas and Other Operations — 43 120 237 Subtotal Energy Group 150 117 400 427 Energy Services: On-Site Energy Production 2,433 1,835 6,409 6,110 Corporate and Services 2,857 2,376 8,784 6,016 Subtotal 10,249 8,374 30,705 25,233 Intersegment Borrowings (2,142 ) (1,606 ) (6,523 ) (4,535 ) Total Interest Charges $ 8,107 $ 6,768 $ 24,182 $ 20,698 Three Months Ended Nine Months Ended 2015 2014 2015 2014 Income Taxes: Gas Utility Operations $ (2,871 ) $ 534 26,593 25,440 Energy Group: Wholesale Energy Operations (4,615 ) (3,896 ) 2,238 (7,077 ) Retail Gas and Other Operations (2,038 ) (121 ) (370 ) 895 Retail Electric Operations 422 152 419 (213 ) Subtotal Energy Group (6,231 ) (3,865 ) 2,287 (6,395 ) Energy Services: On-Site Energy Production (2,015 ) (5,092 ) (26,923 ) (25,521 ) Appliance Service Operations 94 39 191 227 Subtotal Energy Services (1,921 ) (5,053 ) (26,732 ) (25,294 ) Corporate and Services 55 59 218 283 Total Income Taxes $ (10,968 ) $ (8,325 ) $ 2,366 $ (5,966 ) Property Additions: Gas Utility Operations $ 55,335 $ 56,414 $ 160,836 $ 148,012 Energy Group: Wholesale Energy Operations 4 — 383 10 Retail Gas and Other Operations 642 563 1,763 960 Subtotal Energy Group 646 563 2,146 970 Energy Services: On-Site Energy Production 36,805 22,194 67,226 47,769 Appliance Service Operations 51 8 379 14 Subtotal Energy Services 36,856 22,202 67,605 47,783 Corporate and Services 193 1,144 1,794 2,725 Total Property Additions $ 93,030 $ 80,323 $ 232,381 $ 199,490 September 30, 2015 December 31, 2014 Identifiable Assets: Gas Utility Operations $ 2,288,303 $ 2,185,672 Energy Group: Wholesale Energy Operations 240,476 366,119 Retail Gas and Other Operations 37,658 53,073 Retail Electric Operations 46,148 23,682 Subtotal Energy Group 324,282 442,874 Energy Services: On-Site Energy Production 711,194 675,937 Appliance Service Operations 4,080 3,105 Subtotal Energy Services 715,274 679,042 Discontinued Operations 1,582 1,758 Corporate and Services 590,392 527,691 Intersegment Assets (520,325 ) (487,612 ) Total Identifiable Assets $ 3,399,508 $ 3,349,425

RATES AND REGULATORY ACTIONS

RATES AND REGULATORY ACTIONS	9 Months Ended
RATES AND REGULATORY ACTIONS	Sep. 30, 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). In May 2015, the BPU approved an $18.2 million decrease in annual revenues collected from customers through the Societal Benefits Clause ("SBC") charge and the Transportation Initiation Clause ("TIC") charge, comprised of a $6.2 million decrease in revenues from the Remediation Adjustment Clause (“RAC”) component of the SBC, an $11.5 million decrease in revenues from the Clean Energy Program (“CLEP”) component of the SBC and a $0.5 million decrease in TIC revenues, effective June 1, 2015. The decreases in the RAC and CLEP components of the SBC are primarily driven by the accumulation of prior year over-recoveries, as rate recovery exceeded program costs. The decrease in the TIC is being caused by a decrease in costs. The SBC and TIC allow SJG to recover costs associated with certain State-mandated programs. In June 2015, SJG filed its annual Energy Efficiency Tracker (“EET”) rate adjustment petition, requesting a $7.6 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with energy efficiency programs ("EEPs"). SJG's original EEPs, approved by the BPU in 2009, and its EEP extension, approved by the BPU in 2013, ended in July 2013 and June 2015, respectively. The revenue requirements associated with these prior investments decrease over time as they are amortized and recovered. Also contributing to the revenue decrease is the forecasted October 2015 over-recovery of $1.7 million , which further reduces the revenue requirement for the upcoming EET year. This petition is currently pending. In August 2015, the BPU approved a two year extension of SJG's EEPs through August 31, 2017, with a program budget of $36.3 million . SJG will recover the costs of these programs, and earn an allowed return on its investments, through the EET rate recovery mechanism that has been utilized for its EEPs since 2009. The BPU’s approval also permitted SJG to adjust its EET rate effective September 1, 2015 to increase annual revenues by $2.6 million to recover the projected costs of, and the allowed return on, the first year of its investments in the EEPs. In September 2015, the BPU approved SJG’s request, related to its Storm Hardening and Reliability Program (“SHARP”), to increase annual revenues from base rates by $4.0 million to reflect approximately $36.6 million of investments made for storm hardening efforts for the period July 2014 through June 2015. This base rate adjustment became effective on October 1, 2015. Also in September 2015, the BPU approved SJG's annual Basic Gas Supply Service (“BGSS”) and Conservation Incentive Program (“CIP”) rate adjustment petition, which requested a $39.7 million decrease in annual revenues to be implemented on October 1, 2015, comprised of a $28.4 million decrease in BGSS revenues and an $11.3 million decrease in CIP revenues. The level of BGSS revenues is based on forecasted gas costs and customer usage information for the upcoming BGSS/CIP year, which runs from October to September. SJG’s request is based on decreases in forecasted gas commodity costs for the upcoming BGSS/CIP year. The decrease in CIP revenues is caused primarily by higher than normal customer usage caused by weather that was 10.4% colder than normal during the 2014-2015 winter season. Additionally, in September 2015, the BPU approved the statewide Universal Service Fund (“USF”) budget of $46.4 million for all the State’s gas utilities. SJG’s portion of the total budget is approximately $5.2 million . Effective October 1, 2015, the BPU approved a $3.4 million decrease to SJG’s USF recoveries. The BGSS, CIP and USF revenue decreases noted above do not impact SJG's earnings. They represent decreases in the cash requirements of SJG corresponding to lower costs and/or the return of previously over-recovered costs associated with each respective mechanism. 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

REGULATORY ASSETS & REGULATORY LIABILITIES	9 Months Ended
REGULATORY ASSETS & REGULATORY LIABILITIES	Sep. 30, 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): September 30, 2015 December 31, 2014 Environmental Remediation Costs: Expended - Net $ 32,797 $ 29,540 Liability for Future Expenditures 125,466 124,308 Deferred Asset Retirement Obligation Costs 31,976 31,584 Deferred Pension and Other Postretirement Benefit Costs 99,040 99,040 Deferred Gas Costs - Net 19,187 32,202 Societal Benefit Costs Receivable — 385 Deferred Interest Rate Contracts 7,918 7,325 Energy Efficiency Tracker 545 11,247 Pipeline Supplier Service Charges 4,192 5,441 Pipeline Integrity Cost 4,544 3,431 AFUDC - Equity Related Deferrals 11,188 10,781 Other Regulatory Assets 2,339 1,876 Total Regulatory Assets $ 339,192 $ 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 2015 as a result of lower natural gas prices and an increase in the BGSS rate effective October 2014. SJG's BGSS mechanism is designed to overcollect 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 nine months of 2015 resulting from extremely cold weather during the first half of the year. Regulatory Liabilities consisted of the following items (in thousands): September 30, 2015 December 31, 2014 Excess Plant Removal Costs $ 34,040 $ 35,940 Conservation Incentive Program Payable 18,616 4,700 Societal Benefit Costs 9,805 — Other Regulatory Liabilities — 1,259 Total Regulatory Liabilities $ 62,461 $ 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 nine months of 2015 resulting in a payable. This is primarily the result of extremely cold weather experienced in the region during the first half of the year. 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 $9.8 million regulatory liability is due to current SBC rates which are producing recoveries greater than SBC costs. 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 was approved and new rates went into effect on June 1, 2015.

PENSION AND OTHER POSTRETIREMEN

PENSION AND OTHER POSTRETIREMENT BENEFITS	9 Months Ended
PENSION AND OTHER POSTRETIREMENT BENEFITS	Sep. 30, 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 and nine months ended September 30, 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 Nine Months Ended 2015 2014 2015 2014 Service Cost $ 1,334 $ 813 $ 4,003 $ 3,383 Interest Cost 2,792 2,661 8,376 8,051 Expected Return on Plan Assets (3,697 ) (3,262 ) (11,092 ) (9,792 ) Amortizations: Prior Service Cost 53 45 159 131 Actuarial Loss 2,652 1,398 7,956 4,250 Net Periodic Benefit Cost 3,134 1,655 9,402 6,023 Capitalized Benefit Cost (1,216 ) (577 ) (3,649 ) (2,285 ) Deferred Benefit Cost (341 ) — (666 ) — Total Net Periodic Benefit Expense $ 1,577 $ 1,078 $ 5,087 $ 3,738 Other Postretirement Benefits Three Months Ended Nine Months Ended 2015 2014 2015 2014 Service Cost $ 279 $ 168 $ 837 $ 668 Interest Cost 743 659 2,230 2,139 Expected Return on Plan Assets (748 ) (688 ) (2,245 ) (2,062 ) Amortizations: Prior Service Cost 152 38 456 114 Actuarial Loss 336 245 1,007 731 Net Periodic Benefit Cost 762 422 2,285 1,590 Capitalized Benefit Cost (264 ) (42 ) (792 ) (460 ) Deferred Benefit Cost (89 ) — (168 ) — Total Net Periodic Benefit Expense $ 409 $ 380 $ 1,325 $ 1,130 Capitalized benefit costs reflected in the table above relate to SJG’s construction program. Deferred benefit costs relate to SJG's deferral of incremental expense associated with the adoption of new mortality tables (RP-2014 base table with MP-2014 generational projection scale) in 2015. Deferred benefit costs are expected to be recovered through rates as part of SJG's next base rate case. 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	9 Months Ended
LINES OF CREDIT	Sep. 30, 2015
Line of Credit Facility [Abstract]
LINES OF CREDIT	LINES OF CREDIT: Credit facilities and available liquidity as of September 30, 2015 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 89,900 (A) $ 110,100 May 2018 Uncommitted Bank Lines 10,000 — 10,000 Various Total SJG 210,000 89,900 120,100 SJI: Revolving Credit Facility 400,000 270,200 (B) 129,800 February 2018 Total SJI 400,000 270,200 129,800 Total $ 610,000 $ 360,100 $ 249,900 (A) Includes letters of credit outstanding in the amount of $0.6 million . (B) Includes letters of credit outstanding in the amount of $8.1 million . The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.03% and 0.83% at September 30, 2015 and 2014 , respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the nine months ended September 30, 2015 and 2014 were $310.8 million and $291.6 million , respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the nine months ended September 30, 2015 and 2014 were $432.4 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 September 30, 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	9 Months Ended
COMMITMENTS AND CONTINGENCIES	Sep. 30, 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 September 30, 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 September 30, 2015 , 50% of the currently outstanding debt is $8.2 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 September 30, 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 September 30, 2015 , SJI had issued $5.7 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 44.0% of our workforce at September 30, 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 September 30, 2015 , SJI provided $8.1 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. SJG provided a $0.6 million letter of credit under its revolving credit facility to support the remediation of environmental conditions at certain locations in SJG's service territory. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facilities 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 September 30, 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	9 Months Ended
DERIVATIVE INSTRUMENTS	Sep. 30, 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 September 30, 2015 , the Company had outstanding derivative contracts intended to limit the exposure to market risk on 55.5 MMdts (1 MMdts = one million decatherms) of expected future purchases of natural gas, 44.8 MMdts of expected future sales of natural gas, 2.9 MMmwh (1 MMmwh = one million megawatt hours) of expected future purchases of electricity and 2.8 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 226.3 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 September 30, 2015 and December 31, 2014 , are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP September 30, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Energy-related commodity contracts: Derivatives – Energy Related – Current $ 60,536 $ 86,793 $ 85,368 $ 109,744 Derivatives – Energy Related – Non-Current 17,138 23,490 13,905 19,926 Interest rate contracts: Derivatives - Other — 11,518 — 10,732 Total derivatives not designated as hedging instruments under GAAP 77,674 121,801 99,273 140,402 Total Derivatives $ 77,674 $ 121,801 $ 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 September 30, 2015 and December 31, 2014 , information related to these offsetting arrangements were as follows (in thousands): As of September 30, 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 $ 77,674 $ — $ 77,674 $ (30,785 ) (A) $ — $ 46,889 Derivatives - Energy Related Liabilities $ (110,283 ) $ — $ (110,283 ) $ 30,785 (B) $ 30,856 $ (48,642 ) Derivatives - Other $ (11,518 ) $ — $ (11,518 ) $ — $ — $ (11,518 ) 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 September 30, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at September 30, 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 and nine months ended September 30, 2015 and 2014 are as follows (in thousands): Three Months Ended Nine Months Ended Derivatives in Cash Flow Hedging Relationships under GAAP 2015 2014 2015 2014 Interest Rate Contracts: Losses recognized in AOCL on effective portion $ — $ — $ — $ — Losses reclassified from AOCL into income (a) $ (93 ) $ (112 ) $ (303 ) $ (336 ) Gains (losses) recognized in income on ineffective portion (a) $ — $ — $ — $ — (a) Included in Interest Charges Three Months Ended Nine Months Ended Derivatives Not Designated as Hedging Instruments under GAAP 2015 2014 2015 2014 Losses on energy-related commodity contracts (a) $ (11,992 ) $ (1,633 ) $ (4,014 ) $ (30,429 ) (Losses) gains on interest rate contracts (b) (435 ) 202 (192 ) (103 ) Total $ (12,427 ) $ (1,431 ) $ (4,206 ) $ (30,532 ) (a) Included in Operating Revenues - Nonutility (b) Included in Interest Charges Net realized loss of $1.6 million and $1.2 million associated with SJG's energy-related financial commodity contracts for the three months ended September 30, 2015 and 2014 , respectively, and a loss of $6.4 million and a gain of $2.4 million for the nine months ended September 30, 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 September 30, 2015 , is $44.3 million . If the credit risk-related contingent features underlying these agreements were triggered on September 30, 2015 , the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $39.8 million after offsetting asset positions with the same counterparties under master netting arrangements.

FAIR VALUE OF FINANCIAL ASSETS

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	9 Months Ended
FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	Sep. 30, 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 September 30, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 14,371 $ 5,759 $ 8,612 $ — Derivatives – Energy Related Assets (B) 77,674 9,991 27,351 40,332 $ 92,045 $ 15,750 $ 35,963 $ 40,332 Liabilities Derivatives – Energy Related Liabilities (B) $ 110,283 $ 34,536 $ 20,750 $ 54,997 Derivatives – Other (C) 11,518 — 11,518 — $ 121,801 $ 34,536 $ 32,268 $ 54,997 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 September 30, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $19,113 $35,812 Discounted Cash Flow Forward price (per dt) $0.95 - $9.83 [$0.45] (A) Forward Contract - Electric $21,219 $19,185 Discounted Cash Flow Fixed electric load profile (on-peak) 8.47% - 100.00% [56.44%] (B) Fixed electric load profile (off-peak) 0.00% - 91.53% [43.56%] (B) 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)] (A) Forward Contract - Electric $8,020 $6,231 Discounted Cash Flow Fixed electric load profile (on-peak) 8.06% - 100.00% [55.97%] (B) Fixed electric load profile (off-peak) 0.00% - 91.94% [44.03%] (B) (A) Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas. (B) Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak. The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and nine months ended September 30, 2015 and 2014 , using significant unobservable inputs (Level 3), are as follows (in thousands): Three Months Ended Nine Months Ended Balance at beginning of period $ (2,544 ) $ (5,608 ) Other changes in fair value from continuing and new contracts, net (10,725 ) (12,787 ) Transfers in/(out) of Level 3 (A) — 2,054 Settlements (1,396 ) 1,676 Balance at end of period $ (14,665 ) $ (14,665 ) Three Months Ended Nine Months Ended September 30, 2014 Balance at beginning of period $ (4,769 ) $ 8,095 Other changes in fair value from continuing and new contracts, net (423 ) (14,799 ) Settlements 2,493 4,005 Balance at end of period $ (2,699 ) $ (2,699 ) (A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the nine months ended September 30, 2015 , $2.1 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data. Total losses included in earnings for the three and nine months ended September 30, 2015 that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of September 30, 2015 , are $10.7 million and $12.8 million , respectively. These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

LONG-TERM DEBT

LONG-TERM DEBT	9 Months Ended
LONG-TERM DEBT	Sep. 30, 2015
Long-term Debt, Unclassified [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT: In June 2015, the Company redeemed at maturity $64.0 million aggregate principal amount of 2.39% Senior Notes. In August 2015, SJG retired $10.0 million aggregate principal amount of 5.387% Medium Term Notes at maturity. In September 2015, SJG issued $80.0 million of long-term debt under a $200.00 million aggregate syndicated bank term facility. The total outstanding amount under this facility as of September 30, 2015 was $139.0 million . The Company did not issue any other long-term debt during the nine months ended September 30, 2015 . Also in September 2015, SJG redeemed early $0.1 million of the $25.0 million aggregate principal amount variable rate demand bonds that were issued in September 2008. SJG had previously spent all but $0.1 million of the debt proceeds and was permitted under the debt agreement to utilize those remaining funds to redeem the debt early. No other debt was redeemed during the nine months ended September 30, 2015 .

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE LOSS	9 Months Ended
ACCUMULATED OTHER COMPREHENSIVE LOSS	Sep. 30, 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 and nine months ended September 30, 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 July 1, 2015 (a) $ (27,663 ) $ (2,331 ) $ (51 ) $ (106 ) $ (30,151 ) Other comprehensive loss before reclassifications — — (276 ) — (276 ) Amounts reclassified from AOCL (b) — 52 99 (96 ) 55 Net current period other comprehensive income (loss) — 52 (177 ) (96 ) (221 ) Balance at September 30, 2015 (a) $ (27,663 ) $ (2,279 ) $ (228 ) $ (202 ) $ (30,372 ) 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 — — (227 ) — (227 ) Amounts reclassified from AOCL (b) — 171 74 (132 ) 113 Net current period other comprehensive income (loss) — 171 (153 ) (132 ) (114 ) Balance at September 30, 2015 (a) $ (27,663 ) $ (2,279 ) $ (228 ) $ (202 ) $ (30,372 ) (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 and nine months ended September 30, 2015 : Amounts Reclassified from AOCL (in thousands) Affected Line Item in the Condensed Consolidated Statements of Income Three Months Ended Nine Months Ended Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 93 $ 303 Interest Charges Income Taxes (41 ) (132 ) Income Taxes (a) $ 52 $ 171 Unrealized Loss on Available-for-Sale Securities $ 168 $ 127 Other Income Income Taxes (69 ) (53 ) Income Taxes (a) $ 99 $ 74 Loss of Affiliated Companies $ (158 ) $ (218 ) Equity in Loss of Affiliated Companies Income Taxes 62 86 Income Taxes (a) $ (96 ) $ (132 ) Losses from reclassifications for the period net of tax $ 55 $ 113 (a) For 2015, determined using a combined average statutory tax rate of 40% .

SUBSEQUENT EVENT

SUBSEQUENT EVENT	9 Months Ended
SUBSEQUENT EVENT	Sep. 30, 2015
Subsequent Events [Abstract]
SUBSEQUENT EVENT	SUBSEQUENT EVENT: In October 2015, SJI entered into an unsecured $50.0 million term loan, which matures in October 2020. This agreement replaces existing facilities that were set to expire in October 2015.

SUMMARY OF SIGNIFICANT ACCOUN23

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	Sep. 30, 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 (Midstream) 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.
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 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, 2017. 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, including interim periods within those annual periods, beginning after December 15, 2015, 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, including interim periods within those annual periods, beginning after December 15, 2015. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. Also in April 2015, the FASB issued ASU 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40) . This ASU provides guidance to customers (a) in determining whether a cloud computing arrangement includes a software license, and (b) on how the arrangement should be accounted for, depending on whether or not it includes a software license. The amended guidance is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results. In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory . This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, 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 2015, the FASB issued ASU 2015-13, Derivatives and Hedging (Topic 815): Application of the Normal Purchases and Normal Sales Scope Exception to Certain Electricity Contracts within Nodal Energy Markets . This ASU clarifies that for a contract involving the purchase or sale of electricity on a forward basis, companies have the option to elect the normal purchases and normal sales scope exception. Since such contracts meet the physical delivery criterion when the delivery location is within a nodal energy market (i.e., an interconnected electricity grid operated by an independent system operator with established price points at each node or hub location), the ASU notes that it does not constitute net settlement and, consequently, does not cause such a contract to fail to meet the physical delivery criterion. The standard is effective immediately and should be applied prospectively to qualifying contracts existing on August 10, 2015, the date the ASU was issued. The adoption of this standard did not have an impact on the Company's financial statement results. In August 2015, the FASB issued ASU 2015-15, Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements. This ASU states that, given the absence of authoritative guidance for debt issuance costs related to line-of-credit arrangements within ASU 2015-03 (defined above), the SEC staff would not object to an entity deferring and presenting such costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of credit arrangement. The adoption of this standard did not have an impact on the Company's financial statement results.
FAIR VALUE	(A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy. (B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry-standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore, no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry-standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. (C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

STOCK-BASED COMPENSATION PLAN (

STOCK-BASED COMPENSATION PLAN (Tables)	9 Months Ended
STOCK-BASED COMPENSATION PLAN (Tables)	Sep. 30, 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 September 30, 2015 and the assumptions used to estimate the fair value of the awards: Grants Shares Outstanding Fair Value Per Share Expected Volatility Risk-Free Interest Rate Officers & Key Employees - 2013 - TSR 45,622 $ 22.19 21.1 % 0.40 % 2013 - EPS 45,622 $ 25.59 N/A N/A 2014 - TSR 51,349 $ 21.31 20.0 % 0.80 % 2014 - EPS 51,349 $ 27.22 N/A N/A 2015 - TSR 34,574 $ 26.31 16.0 % 1.10 % 2015 - EPS, ROE, Time 88,919 $ 29.47 N/A N/A Directors - 2015 26,338 $ 29.21 N/A N/A
Summary of the total stock-based compensation cost for the period	The following table summarizes the total stock-based compensation cost for the three and nine months ended September 30, 2015 and 2014 (in thousands): Three Months Ended Nine Months Ended 2015 2014 2015 2014 Officers & Key Employees $ 654 $ 584 $ 1,964 $ 1,751 Directors 205 159 577 475 Total Cost 859 743 2,541 2,226 Capitalized (92 ) (70 ) (270 ) (210 ) Net Expense $ 767 $ 673 $ 2,271 $ 2,016
Summary of information regarding restricted stock award activity during the period excluding accrued dividend equivalents	The following table summarizes information regarding restricted stock award activity during the nine months ended September 30, 2015 , excluding accrued dividend equivalents: Officers &Other Key Employees Directors Weighted Average Fair Value Nonvested Shares Outstanding, January 1, 2015 223,876 23,220 $ 24.40 Granted 158,929 26,338 $ 28.67 Cancelled/Forfeited (65,370 ) — $ 26.56 Vested — (23,220 ) $ 27.26 Nonvested Shares Outstanding, September 30, 2015 317,435 26,338 $ 26.10

DISCONTINUED OPERATIONS AND A25

DISCONTINUED OPERATIONS AND AFFILIATIONS (Tables)	9 Months Ended
DISCONTINUED OPERATIONS AND AFFILIATIONS (Tables)	Sep. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Summarized operating results of the discontinued operations	Summarized operating results of the discontinued operations for the three and nine months ended September 30 , 2015 and 2014, were (in thousands, except per share amounts): Three Months Ended Nine Months Ended 2015 2014 2015 2014 Loss Before Income Taxes: Sand Mining $ (17 ) $ (79 ) $ (381 ) $ (562 ) Fuel Oil (123 ) (105 ) (286 ) (227 ) Income Tax Benefits 49 64 226 276 Loss from Discontinued Operations — Net $ (91 ) $ (120 ) $ (441 ) $ (513 ) Earnings (Loss) Per Common Share from Discontinued Operations — Net: Basic and Diluted $ — $ — $ (0.01 ) $ —
Equity Method Investments	The following table presents summarized income statement information of the total balances for Energenic (of which SJI has only a 50% equity interest) accounted for under the equity method (in thousands): Three Months Ended Nine Months Ended 2015 2014 2015 2014 Revenues $ 18,183 $ 27,160 $ 63,812 $ 83,380 Cost of Sales $ 5,048 $ 5,390 $ 16,452 $ 20,588 Loss from continuing operations $ (4,984 ) $ (4,154 ) $ (42,367 ) $ (4,139 ) Net Loss $ (4,984 ) $ (4,154 ) $ (42,367 ) $ (4,139 )

COMMON STOCK (Tables)

COMMON STOCK (Tables)	9 Months Ended
COMMON STOCK (Tables)	Sep. 30, 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 366,262 Stock-Based Compensation Plan 26,338 Ending Balance, September 30 68,727,460

SEGMENTS OF BUSINESS (Tables)

SEGMENTS OF BUSINESS (Tables)	9 Months Ended
SEGMENTS OF BUSINESS (Tables)	Sep. 30, 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 Nine Months Ended 2015 2014 2015 2014 Operating Revenues: Gas Utility Operations $ 58,634 $ 60,952 $ 402,104 $ 340,656 Energy Group: Wholesale Energy Operations 9,352 (3,538 ) 77,973 28,898 Retail Gas and Other Operations 11,757 18,900 67,900 95,281 Retail Electric Operations 44,240 29,961 110,203 98,233 Subtotal Energy Group 65,349 45,323 256,076 222,412 Energy Services: On-Site Energy Production 18,898 16,453 47,606 42,196 Appliance Service Operations 2,290 2,319 7,346 7,610 Subtotal Energy Services 21,188 18,772 54,952 49,806 Corporate & Services 6,925 7,001 23,776 21,324 Subtotal 152,096 132,048 736,908 634,198 Intersegment Sales (11,034 ) (9,621 ) (35,183 ) (28,299 ) Total Operating Revenues $ 141,062 $ 122,427 $ 701,725 $ 605,899 Three Months Ended Nine Months Ended 2015 2014 2015 2014 Operating (Loss) Income: Gas Utility Operations $ (2,501 ) $ 3,368 $ 82,649 $ 75,813 Energy Group: Wholesale Energy Operations (11,813 ) (10,314 ) 3,675 (20,437 ) Retail Gas and Other Operations (4,821 ) (390 ) (1,581 ) 1,387 Retail Electric Operations 1,034 373 1,026 (521 ) Subtotal Energy Group (15,600 ) (10,331 ) 3,120 (19,571 ) Energy Services: On-Site Energy Production 2,265 2,171 3,960 4,547 Appliance Service Operations 216 60 411 322 Subtotal Energy Services 2,481 2,231 4,371 4,869 Corporate and Services 567 619 1,518 1,041 Total Operating (Loss) Income $ (15,053 ) $ (4,113 ) $ 91,658 $ 62,152 Depreciation and Amortization: Gas Utility Operations $ 14,911 $ 12,942 $ 43,317 $ 38,375 Energy Group: Wholesale Energy Operations 191 37 238 123 Retail Gas and Other Operations 39 19 79 61 Subtotal Energy Group 230 56 317 184 Energy Services: On-Site Energy Production 7,650 6,540 22,158 18,480 Appliance Service Operations 85 68 232 202 Subtotal Energy Services 7,735 6,608 22,390 18,682 Corporate and Services 261 (41 ) 961 413 Total Depreciation and Amortization $ 23,137 $ 19,565 $ 66,985 $ 57,654 Interest Charges: Gas Utility Operations $ 4,809 $ 4,046 $ 15,112 $ 12,680 Energy Group: Wholesale Energy Operations 150 74 280 190 Retail Gas and Other Operations — 43 120 237 Subtotal Energy Group 150 117 400 427 Energy Services: On-Site Energy Production 2,433 1,835 6,409 6,110 Corporate and Services 2,857 2,376 8,784 6,016 Subtotal 10,249 8,374 30,705 25,233 Intersegment Borrowings (2,142 ) (1,606 ) (6,523 ) (4,535 ) Total Interest Charges $ 8,107 $ 6,768 $ 24,182 $ 20,698 Three Months Ended Nine Months Ended 2015 2014 2015 2014 Income Taxes: Gas Utility Operations $ (2,871 ) $ 534 26,593 25,440 Energy Group: Wholesale Energy Operations (4,615 ) (3,896 ) 2,238 (7,077 ) Retail Gas and Other Operations (2,038 ) (121 ) (370 ) 895 Retail Electric Operations 422 152 419 (213 ) Subtotal Energy Group (6,231 ) (3,865 ) 2,287 (6,395 ) Energy Services: On-Site Energy Production (2,015 ) (5,092 ) (26,923 ) (25,521 ) Appliance Service Operations 94 39 191 227 Subtotal Energy Services (1,921 ) (5,053 ) (26,732 ) (25,294 ) Corporate and Services 55 59 218 283 Total Income Taxes $ (10,968 ) $ (8,325 ) $ 2,366 $ (5,966 ) Property Additions: Gas Utility Operations $ 55,335 $ 56,414 $ 160,836 $ 148,012 Energy Group: Wholesale Energy Operations 4 — 383 10 Retail Gas and Other Operations 642 563 1,763 960 Subtotal Energy Group 646 563 2,146 970 Energy Services: On-Site Energy Production 36,805 22,194 67,226 47,769 Appliance Service Operations 51 8 379 14 Subtotal Energy Services 36,856 22,202 67,605 47,783 Corporate and Services 193 1,144 1,794 2,725 Total Property Additions $ 93,030 $ 80,323 $ 232,381 $ 199,490 September 30, 2015 December 31, 2014 Identifiable Assets: Gas Utility Operations $ 2,288,303 $ 2,185,672 Energy Group: Wholesale Energy Operations 240,476 366,119 Retail Gas and Other Operations 37,658 53,073 Retail Electric Operations 46,148 23,682 Subtotal Energy Group 324,282 442,874 Energy Services: On-Site Energy Production 711,194 675,937 Appliance Service Operations 4,080 3,105 Subtotal Energy Services 715,274 679,042 Discontinued Operations 1,582 1,758 Corporate and Services 590,392 527,691 Intersegment Assets (520,325 ) (487,612 ) Total Identifiable Assets $ 3,399,508 $ 3,349,425

REGULATORY ASSETS & REGULATOR28

REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)	9 Months Ended
REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)	Sep. 30, 2015
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets	Regulatory Assets consisted of the following items (in thousands): September 30, 2015 December 31, 2014 Environmental Remediation Costs: Expended - Net $ 32,797 $ 29,540 Liability for Future Expenditures 125,466 124,308 Deferred Asset Retirement Obligation Costs 31,976 31,584 Deferred Pension and Other Postretirement Benefit Costs 99,040 99,040 Deferred Gas Costs - Net 19,187 32,202 Societal Benefit Costs Receivable — 385 Deferred Interest Rate Contracts 7,918 7,325 Energy Efficiency Tracker 545 11,247 Pipeline Supplier Service Charges 4,192 5,441 Pipeline Integrity Cost 4,544 3,431 AFUDC - Equity Related Deferrals 11,188 10,781 Other Regulatory Assets 2,339 1,876 Total Regulatory Assets $ 339,192 $ 357,160
Schedule of Regulatory Liabilities	Regulatory Liabilities consisted of the following items (in thousands): September 30, 2015 December 31, 2014 Excess Plant Removal Costs $ 34,040 $ 35,940 Conservation Incentive Program Payable 18,616 4,700 Societal Benefit Costs 9,805 — Other Regulatory Liabilities — 1,259 Total Regulatory Liabilities $ 62,461 $ 41,899

PENSION AND OTHER POSTRETIREM29

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	9 Months Ended
PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	Sep. 30, 2015
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
Schedule of defined benefit plans disclosures	For the three and nine months ended September 30, 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 Nine Months Ended 2015 2014 2015 2014 Service Cost $ 1,334 $ 813 $ 4,003 $ 3,383 Interest Cost 2,792 2,661 8,376 8,051 Expected Return on Plan Assets (3,697 ) (3,262 ) (11,092 ) (9,792 ) Amortizations: Prior Service Cost 53 45 159 131 Actuarial Loss 2,652 1,398 7,956 4,250 Net Periodic Benefit Cost 3,134 1,655 9,402 6,023 Capitalized Benefit Cost (1,216 ) (577 ) (3,649 ) (2,285 ) Deferred Benefit Cost (341 ) — (666 ) — Total Net Periodic Benefit Expense $ 1,577 $ 1,078 $ 5,087 $ 3,738 Other Postretirement Benefits Three Months Ended Nine Months Ended 2015 2014 2015 2014 Service Cost $ 279 $ 168 $ 837 $ 668 Interest Cost 743 659 2,230 2,139 Expected Return on Plan Assets (748 ) (688 ) (2,245 ) (2,062 ) Amortizations: Prior Service Cost 152 38 456 114 Actuarial Loss 336 245 1,007 731 Net Periodic Benefit Cost 762 422 2,285 1,590 Capitalized Benefit Cost (264 ) (42 ) (792 ) (460 ) Deferred Benefit Cost (89 ) — (168 ) — Total Net Periodic Benefit Expense $ 409 $ 380 $ 1,325 $ 1,130

LINES OF CREDIT (Tables)

LINES OF CREDIT (Tables)	9 Months Ended
LINES OF CREDIT (Tables)	Sep. 30, 2015
Line of Credit Facility [Abstract]
Schedule of lines of credit	Credit facilities and available liquidity as of September 30, 2015 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 89,900 (A) $ 110,100 May 2018 Uncommitted Bank Lines 10,000 — 10,000 Various Total SJG 210,000 89,900 120,100 SJI: Revolving Credit Facility 400,000 270,200 (B) 129,800 February 2018 Total SJI 400,000 270,200 129,800 Total $ 610,000 $ 360,100 $ 249,900 (A) Includes letters of credit outstanding in the amount of $0.6 million . (B) Includes letters of credit outstanding in the amount of $8.1 million .

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	9 Months Ended
DERIVATIVE INSTRUMENTS (Tables)	Sep. 30, 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 September 30, 2015 and December 31, 2014 , are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP September 30, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Energy-related commodity contracts: Derivatives – Energy Related – Current $ 60,536 $ 86,793 $ 85,368 $ 109,744 Derivatives – Energy Related – Non-Current 17,138 23,490 13,905 19,926 Interest rate contracts: Derivatives - Other — 11,518 — 10,732 Total derivatives not designated as hedging instruments under GAAP 77,674 121,801 99,273 140,402 Total Derivatives $ 77,674 $ 121,801 $ 99,273 $ 140,402
Offsetting assets	As of September 30, 2015 and December 31, 2014 , information related to these offsetting arrangements were as follows (in thousands): As of September 30, 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 $ 77,674 $ — $ 77,674 $ (30,785 ) (A) $ — $ 46,889 Derivatives - Energy Related Liabilities $ (110,283 ) $ — $ (110,283 ) $ 30,785 (B) $ 30,856 $ (48,642 ) Derivatives - Other $ (11,518 ) $ — $ (11,518 ) $ — $ — $ (11,518 ) 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 September 30, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at September 30, 2015 and December 31, 2014 were related to derivative assets which can be net settled against derivative liabilities.
Offsetting liabilities	As of September 30, 2015 and December 31, 2014 , information related to these offsetting arrangements were as follows (in thousands): As of September 30, 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 $ 77,674 $ — $ 77,674 $ (30,785 ) (A) $ — $ 46,889 Derivatives - Energy Related Liabilities $ (110,283 ) $ — $ (110,283 ) $ 30,785 (B) $ 30,856 $ (48,642 ) Derivatives - Other $ (11,518 ) $ — $ (11,518 ) $ — $ — $ (11,518 ) 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 September 30, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at September 30, 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 and nine months ended September 30, 2015 and 2014 are as follows (in thousands): Three Months Ended Nine Months Ended Derivatives in Cash Flow Hedging Relationships under GAAP 2015 2014 2015 2014 Interest Rate Contracts: Losses recognized in AOCL on effective portion $ — $ — $ — $ — Losses reclassified from AOCL into income (a) $ (93 ) $ (112 ) $ (303 ) $ (336 ) Gains (losses) recognized in income on ineffective portion (a) $ — $ — $ — $ — (a) Included in Interest Charges Three Months Ended Nine Months Ended Derivatives Not Designated as Hedging Instruments under GAAP 2015 2014 2015 2014 Losses on energy-related commodity contracts (a) $ (11,992 ) $ (1,633 ) $ (4,014 ) $ (30,429 ) (Losses) gains on interest rate contracts (b) (435 ) 202 (192 ) (103 ) Total $ (12,427 ) $ (1,431 ) $ (4,206 ) $ (30,532 ) (a) Included in Operating Revenues - Nonutility (b) Included in Interest Charges

FAIR VALUE OF FINANCIAL ASSET32

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 14,371 $ 5,759 $ 8,612 $ — Derivatives – Energy Related Assets (B) 77,674 9,991 27,351 40,332 $ 92,045 $ 15,750 $ 35,963 $ 40,332 Liabilities Derivatives – Energy Related Liabilities (B) $ 110,283 $ 34,536 $ 20,750 $ 54,997 Derivatives – Other (C) 11,518 — 11,518 — $ 121,801 $ 34,536 $ 32,268 $ 54,997 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 September 30, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $19,113 $35,812 Discounted Cash Flow Forward price (per dt) $0.95 - $9.83 [$0.45] (A) Forward Contract - Electric $21,219 $19,185 Discounted Cash Flow Fixed electric load profile (on-peak) 8.47% - 100.00% [56.44%] (B) Fixed electric load profile (off-peak) 0.00% - 91.53% [43.56%] (B) 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)] (A) Forward Contract - Electric $8,020 $6,231 Discounted Cash Flow Fixed electric load profile (on-peak) 8.06% - 100.00% [55.97%] (B) Fixed electric load profile (off-peak) 0.00% - 91.94% [44.03%] (B) (A) Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas. (B) Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak.
Changes in fair value of significant unobservable inputs	The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and nine months ended September 30, 2015 and 2014 , using significant unobservable inputs (Level 3), are as follows (in thousands): Three Months Ended Nine Months Ended Balance at beginning of period $ (2,544 ) $ (5,608 ) Other changes in fair value from continuing and new contracts, net (10,725 ) (12,787 ) Transfers in/(out) of Level 3 (A) — 2,054 Settlements (1,396 ) 1,676 Balance at end of period $ (14,665 ) $ (14,665 ) Three Months Ended Nine Months Ended September 30, 2014 Balance at beginning of period $ (4,769 ) $ 8,095 Other changes in fair value from continuing and new contracts, net (423 ) (14,799 ) Settlements 2,493 4,005 Balance at end of period $ (2,699 ) $ (2,699 ) (A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the nine months ended September 30, 2015 , $2.1 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data.

ACCUMULATED OTHER COMPREHENSI33

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	9 Months Ended
ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	Sep. 30, 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 and nine months ended September 30, 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 July 1, 2015 (a) $ (27,663 ) $ (2,331 ) $ (51 ) $ (106 ) $ (30,151 ) Other comprehensive loss before reclassifications — — (276 ) — (276 ) Amounts reclassified from AOCL (b) — 52 99 (96 ) 55 Net current period other comprehensive income (loss) — 52 (177 ) (96 ) (221 ) Balance at September 30, 2015 (a) $ (27,663 ) $ (2,279 ) $ (228 ) $ (202 ) $ (30,372 ) 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 — — (227 ) — (227 ) Amounts reclassified from AOCL (b) — 171 74 (132 ) 113 Net current period other comprehensive income (loss) — 171 (153 ) (132 ) (114 ) Balance at September 30, 2015 (a) $ (27,663 ) $ (2,279 ) $ (228 ) $ (202 ) $ (30,372 ) (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 and nine months ended September 30, 2015 : Amounts Reclassified from AOCL (in thousands) Affected Line Item in the Condensed Consolidated Statements of Income Three Months Ended Nine Months Ended Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 93 $ 303 Interest Charges Income Taxes (41 ) (132 ) Income Taxes (a) $ 52 $ 171 Unrealized Loss on Available-for-Sale Securities $ 168 $ 127 Other Income Income Taxes (69 ) (53 ) Income Taxes (a) $ 99 $ 74 Loss of Affiliated Companies $ (158 ) $ (218 ) Equity in Loss of Affiliated Companies Income Taxes 62 86 Income Taxes (a) $ (96 ) $ (132 ) Losses from reclassifications for the period net of tax $ 55 $ 113 (a) For 2015, determined using a combined average statutory tax rate of 40% .

SUMMARY OF SIGNIFICANT ACCOUN34

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)	May. 08, 2015	Feb. 26, 2015shares	Sep. 30, 2015USD ($)shares	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)shares	Sep. 30, 2014USD ($)	Feb. 25, 2015shares	Dec. 31, 2014USD ($)shares
Accounting Policies [Abstract]
Common stock, authorized (in shares) \| shares		120,000,000					60,000,000
Stockholders' Equity Note, Stock Split, Conversion Ratio	2	2
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales			$ 200,000	$ 200,000	$ 1,000,000	$ 800,000
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			$ 8,900,000
Shares of treasury stock held (in shares) \| shares			231,749		231,749			263,578

STOCK-BASED COMPENSATION PLAN35

STOCK-BASED COMPENSATION PLAN (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended		12 Months Ended
	Jan. 31, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Sep. 30, 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of options granted (in shares)				0	0
Fair value per share (in dollars per share)	$ 24.40	$ 26.10		$ 24.40		$ 24.40	$ 26.10
Expected volatility, measurement period				3 years
Service period of shares (in years)				3 years
Total Cost		$ 859	$ 743	$ 2,541	$ 2,226
Capitalized		(92)	(70)	(270)	(210)
Net Expense		$ 767	673	$ 2,271	$ 2,016
Unrecognized compensation cost of awards granted under the plan							$ 3,800
Weighted average period over which unrecognized compensation cost is to be recognized (in years)				1 year 9 months 18 days
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-beginning balance (in dollars per share)	$ 24.40			$ 24.40
Weighted average fair value nonvested shares-granted during the period (in dollars per share)				28.67
Weighted average fair value nonvested shares-cancelled/forfeited during the period (in dollars per share)				26.56
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)		$ 26.10		$ 26.10		$ 24.40
Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted				158,929	136,906
The range of the actual amount of shares that ultimately vest of the original share units granted				0% to 200%
Vesting period of shares (in years)				3 years
Shares outstanding (in shares)	223,876	317,435		223,876		223,876	317,435
Total Cost		$ 654	584	$ 1,964	$ 1,751
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)	223,876			223,876
Granted (in shares)				158,929	136,906
Cancelled/Forfeited (in shares)				(65,370)
Vested (in shares)				0
Nonvested shares outstanding, ending balance (in shares)		317,435		317,435		223,876
Additional disclosures [Abstract]
Number of shares awarded during the period				0		0
Officers and Key Employees \| 2013 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)		45,622		45,622			45,622
Fair value per share (in dollars per share)		$ 22.19		$ 22.19			$ 22.19
Expected volatility				21.10%
Risk-free interest rate				0.40%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		45,622		45,622
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)		$ 22.19		$ 22.19
Officers and Key Employees \| 2013 - EPS
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)		45,622		45,622			45,622
Fair value per share (in dollars per share)		$ 25.59		$ 25.59			$ 25.59
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		45,622		45,622
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)		$ 25.59		$ 25.59
Officers and Key Employees \| 2014 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)		51,349		51,349			51,349
Fair value per share (in dollars per share)		$ 21.31		$ 21.31			$ 21.31
Expected volatility				20.00%
Risk-free interest rate				0.80%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		51,349		51,349
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)		$ 21.31		$ 21.31
Officers and Key Employees \| 2014 - EPS
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)		51,349		51,349			51,349
Fair value per share (in dollars per share)		$ 27.22		$ 27.22			$ 27.22
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		51,349		51,349
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)		$ 27.22		$ 27.22
Officers and Key Employees \| 2015 - TSR
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)		34,574		34,574			34,574
Fair value per share (in dollars per share)		$ 26.31		$ 26.31			$ 26.31
Expected volatility				16.00%
Risk-free interest rate				1.10%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		34,574		34,574
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)		$ 26.31		$ 26.31
Officers and Key Employees \| 2015 - EPS, ROE, Time
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)		88,919		88,919			88,919
Fair value per share (in dollars per share)		$ 29.47		$ 29.47			$ 29.47
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		88,919		88,919
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)		$ 29.47		$ 29.47
Director
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted				26,338	23,220
Vesting period of shares (in years)				12 months
Shares Vested, Directors							100.00%
Shares outstanding (in shares)	23,220	26,338		23,220		23,220	26,338
Total Cost		$ 205	$ 159	$ 577	$ 475
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)	23,220			23,220
Granted (in shares)				26,338	23,220
Cancelled/Forfeited (in shares)				0
Vested (in shares)				(23,220)
Nonvested shares outstanding, ending balance (in shares)		26,338		26,338		23,220
Additional disclosures [Abstract]
Fair value of shares issued				$ 800	$ 600
Director \| 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)		26,338		26,338			26,338
Fair value per share (in dollars per share)		$ 29.21		$ 29.21			$ 29.21
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		26,338		26,338
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)		$ 29.21		$ 29.21
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
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Return On Equity Award Threshold				7.00%
Restricted Stock \| Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted	47,678
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)	47,678

DISCONTINUED OPERATIONS AND A36

DISCONTINUED OPERATIONS AND AFFILIATIONS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Loss Before Income Taxes:
Income Tax Benefits	$ 49	$ 64	$ 226	$ 276
Loss from Discontinued Operations — Net	$ (91)	$ (120)	$ (441)	$ (513)
Earnings (Loss) Per Common Share from
Basic and Diluted (in dollars per share)	$ 0	$ 0	$ (0.01)	$ 0
Sand Mining
Loss Before Income Taxes:
Loss Before Income Taxes	$ (17)	$ (79)	$ (381)	$ (562)
Fuel Oil
Loss Before Income Taxes:
Loss Before Income Taxes	$ (123)	$ (105)	$ (286)	$ (227)

DISCONTINUED OPERATIONS AND A37

DISCONTINUED OPERATIONS AND AFFILIATIONS 2 (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015USD ($)mi	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)mi	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Affiliations [Abstract]
Investments in unconsolidated affiliates			$ 4,400	$ 1,300
Notes Receivable - affiliate	$ 49,800		49,800		$ 51,500
Due from Affiliate, Noncurrent, Secured By Property, Plant, And Equipment	$ 38,900		$ 38,900
Interest accrual on secured notes receivable	7.50%		7.50%
Due from Affiliate, Noncurrent, Unsecured	$ 10,900		$ 10,900
Net asset - included in investment in affiliates and other noncurrent liabilities	$ 52,400		52,400
Combined equity contributions and the notes receivable - affiliate			$ 103,000
Energenic US LLC
Affiliations [Abstract]
Equity interest	50.00%		50.00%
Equity Method Investment, Summarized Financial Information [Abstract]
Revenues	$ 18,183	$ 27,160	$ 63,812	83,380
Cost of sales	5,048	5,390	16,452	20,588
Loss from continuing operations	(4,984)	(4,154)	(42,367)	(4,139)
Net Loss	$ (4,984)	$ (4,154)	$ (42,367)	$ (4,139)
Potato Creek, LLC (Potato Creek)
Affiliations [Abstract]
Equity interest	30.00%		30.00%
PennEast Pipeline Company, LLC (PennEast)
Affiliations [Abstract]
Equity interest	20.00%		20.00%
Length of Pipeline (in miles) \| mi	100		100

COMMON STOCK (Details)

COMMON STOCK (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Common Stock [Roll Forward]
Beginning balance (in shares)			68,334,860
New Issues During the Period:
Dividend Reinvestment Plan (in shares)			366,262
Stock-Based Compensation Plan (in shares)			26,338
Ending balance (in shares)	68,727,460		68,727,460
Par value of common stock (in dollars per share)	$ 1.25		$ 1.25
Net excess over par value recorded in premium on common stock			$ 11,400
Incremental shares included in diluted EPS calculation (in shares)	187,758	148,664	198,222	150,592
Proceeds from sale of common stock			$ 9,705	$ 29,125

FINANCIAL INSTRUMENTS (Details)

FINANCIAL INSTRUMENTS (Details) $ in Thousands	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
FINANCIAL INSTRUMENTS (Details) $ in Thousands	Jun. 30, 2015USD ($)term	Jun. 30, 2015USD ($)term	Sep. 30, 2015USD ($)	Dec. 31, 2011	Dec. 31, 2014USD ($)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted investments held In escrow			$ 2,600		$ 1,700
Margin accounts with selected counterparties to support risk management activities			40,800		63,700
Investment in Affiliates			53,237		68,351
Notes Receivable - Affiliate			$ 36,019		36,799
South Jersey Gas Company \| Financing Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivable With Imputed Interest, Term			5 years
Long-term receivables, net of unamortized discount			$ 13,300		15,000
Imputed interest on long term receivables			$ 1,300		$ 1,300
Atlantic City Note Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivable with Imputed Interest, Face Amount	$ 10,000	$ 10,000
Receivable with Imputed Interest, Effective Yield (Interest Rate)	1.00%
Receivable With Imputed Interest, Term	6 months
Receivable With Imputed Interest, Number Of Additional Terms \| term	2	2
Receivable With Imputed Interest, Extension Term	3 months
Energenic US LLC
Accounts, Notes, Loans and Financing Receivable [Line Items]
Equity interest			50.00%
Contract term (in years)				20 years
Equity Method Investment, Other than Temporary Impairment		$ 7,700
Investment in Affiliates			$ 2,000
Notes Receivable - Affiliate			$ 13,900

FINANCIAL INSTRUMENTS 2 (Detail

FINANCIAL INSTRUMENTS 2 (Details) - Derivatives Energy Related Assets - Supplier Concentration Risk $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)
Concentration Risk [Line Items]
Amount of derivatives - energy related assets with single retail counterparty	$ 8.8
Percentage of derivatives - energy related assets with a single retail counterparty	11.40%

FINANCIAL INSTRUMENTS 3 (Detail

FINANCIAL INSTRUMENTS 3 (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
FINANCIAL INSTRUMENTS 3 (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2010
Schedule of Equity Method Investments [Line Items]
Finance obligation to ACB Energy Partners LLC	$ 18,912	$ 19,659
Estimated fair value of long-term debt	1,072,300	1,058,500
Carrying amount of long-term debt	$ 1,015,300	1,009,400
Energenic US LLC
Schedule of Equity Method Investments [Line Items]
Equity interest of Marina in Energenic	50.00%
Marina Energy LLC \| Energenic US LLC
Schedule of Equity Method Investments [Line Items]
Equity interest of Marina in Energenic			50.00%
Other construction costs	$ 23,700	$ 23,700

SEGMENTS OF BUSINESS (Details)

SEGMENTS OF BUSINESS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
SEGMENTS OF BUSINESS (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Operating Revenues	$ 141,062	$ 122,427	$ 701,725	$ 605,899
Operating (Loss) Income	(15,053)	(4,113)	91,658	62,152
Depreciation and Amortization	23,137	19,565	66,985	57,654
Interest Charges	8,107	6,768	24,182	20,698
Income Taxes	(10,968)	(8,325)	2,366	(5,966)
Property Additions	93,030	80,323	232,381	199,490
Identifiable Assets	3,399,508		3,399,508		$ 3,349,425
Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues	152,096	132,048	736,908	634,198
Interest Charges	10,249	8,374	30,705	25,233
Operating Segments \| Energy Group
Segment Reporting Information [Line Items]
Operating Revenues	65,349	45,323	256,076	222,412
Operating (Loss) Income	(15,600)	(10,331)	3,120	(19,571)
Depreciation and Amortization	230	56	317	184
Interest Charges	150	117	400	427
Income Taxes	(6,231)	(3,865)	2,287	(6,395)
Property Additions	646	563	2,146	970
Identifiable Assets	324,282		324,282		442,874
Operating Segments \| Energy Services
Segment Reporting Information [Line Items]
Operating Revenues	21,188	18,772	54,952	49,806
Operating (Loss) Income	2,481	2,231	4,371	4,869
Depreciation and Amortization	7,735	6,608	22,390	18,682
Income Taxes	(1,921)	(5,053)	(26,732)	(25,294)
Property Additions	36,856	22,202	67,605	47,783
Identifiable Assets	715,274		715,274		679,042
Operating Segments \| Gas Utility Operations
Segment Reporting Information [Line Items]
Operating Revenues	58,634	60,952	402,104	340,656
Operating (Loss) Income	(2,501)	3,368	82,649	75,813
Depreciation and Amortization	14,911	12,942	43,317	38,375
Interest Charges	4,809	4,046	15,112	12,680
Income Taxes	(2,871)	534	26,593	25,440
Property Additions	55,335	56,414	160,836	148,012
Identifiable Assets	2,288,303		2,288,303		2,185,672
Operating Segments \| Wholesale Energy Operations \| Energy Group
Segment Reporting Information [Line Items]
Operating Revenues	9,352	(3,538)	77,973	28,898
Operating (Loss) Income	(11,813)	(10,314)	3,675	(20,437)
Depreciation and Amortization	191	37	238	123
Interest Charges	150	74	280	190
Income Taxes	(4,615)	(3,896)	2,238	(7,077)
Property Additions	4	0	383	10
Identifiable Assets	240,476		240,476		366,119
Operating Segments \| Retail Gas and Other Operations \| Energy Group
Segment Reporting Information [Line Items]
Operating Revenues	11,757	18,900	67,900	95,281
Operating (Loss) Income	(4,821)	(390)	(1,581)	1,387
Depreciation and Amortization	39	19	79	61
Interest Charges	0	43	120	237
Income Taxes	(2,038)	(121)	(370)	895
Property Additions	642	563	1,763	960
Identifiable Assets	37,658		37,658		53,073
Operating Segments \| Retail Electric Operations \| Energy Group
Segment Reporting Information [Line Items]
Operating Revenues	44,240	29,961	110,203	98,233
Operating (Loss) Income	1,034	373	1,026	(521)
Income Taxes	422	152	419	(213)
Identifiable Assets	46,148		46,148		23,682
Operating Segments \| On-Site Energy Production \| Energy Services
Segment Reporting Information [Line Items]
Operating Revenues	18,898	16,453	47,606	42,196
Operating (Loss) Income	2,265	2,171	3,960	4,547
Depreciation and Amortization	7,650	6,540	22,158	18,480
Interest Charges	2,433	1,835	6,409	6,110
Income Taxes	(2,015)	(5,092)	(26,923)	(25,521)
Property Additions	36,805	22,194	67,226	47,769
Identifiable Assets	711,194		711,194		675,937
Operating Segments \| Appliance Service Operations \| Energy Services
Segment Reporting Information [Line Items]
Operating Revenues	2,290	2,319	7,346	7,610
Operating (Loss) Income	216	60	411	322
Depreciation and Amortization	85	68	232	202
Income Taxes	94	39	191	227
Property Additions	51	8	379	14
Identifiable Assets	4,080		4,080		3,105
Discontinued Operations
Segment Reporting Information [Line Items]
Identifiable Assets	1,582		1,582		1,758
Corporate and Services
Segment Reporting Information [Line Items]
Operating Revenues	6,925	7,001	23,776	21,324
Operating (Loss) Income	567	619	1,518	1,041
Depreciation and Amortization	261	(41)	961	413
Interest Charges	2,857	2,376	8,784	6,016
Income Taxes	55	59	218	283
Property Additions	193	1,144	1,794	2,725
Identifiable Assets	590,392		590,392		527,691
Intersegment Elimination
Segment Reporting Information [Line Items]
Operating Revenues	(11,034)	(9,621)	(35,183)	(28,299)
Interest Charges	(2,142)	$ (1,606)	(6,523)	$ (4,535)
Identifiable Assets	$ (520,325)		$ (520,325)		$ (487,612)

RATES AND REGULATORY ACTIONS (D

RATES AND REGULATORY ACTIONS (Details) - USD ($) $ in Millions	1 Months Ended
	Sep. 30, 2015	Aug. 31, 2015	Oct. 01, 2015	Jun. 30, 2015	May. 31, 2015
Subsequent Event
Schedule of Capitalization [Line Items]
Public Utilities, Amount of Regulatory Costs Approved, Annual Revenue Impact Increase (Decrease)			$ (3.4)
Societal Benefits Clause And Transportation Initiation Clause
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved					$ (18.2)
Remediation Adjustment Clause
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved					(6.2)
Clean Energy Program
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved					(11.5)
Transportation Initiation Clause
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved					$ (0.5)
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved		$ 2.6		$ (7.6)
Regulatory Costs, Extension Period		2 years
Amount of regulatory costs approved, statewide		$ 36.3
Energy Efficiency Tracker, Over Under Recovery
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved	$ (1.7)
SHARP
Schedule of Capitalization [Line Items]
Approved base rate increase	4
Public Utilities, Investment To Be Recovered	36.6
Basic Gas Supply Service And Conservation Incentive Program
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved	(39.7)
Basic Gas Supply Service
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved	(28.4)
Conservation Incentive Program
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved	$ (11.3)
Public Utilities, Colder Than Normal, Percentage	10.40%
Universal Services Fund
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved	$ 5.2
Amount of regulatory costs approved, statewide	$ 46.4

REGULATORY ASSETS & REGULATOR44

REGULATORY ASSETS & REGULATORY LIABILITIES (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 339,192	$ 357,160
Environmental Remediation Costs: Expended - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	32,797	29,540
Environmental Remediation Costs: Liability for Future Expenditures
Regulatory Assets [Line Items]
Total Regulatory Assets	125,466	124,308
Deferred Asset Retirement Obligation Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	31,976	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	19,187	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	7,918	7,325
Energy Efficiency Tracker
Regulatory Assets [Line Items]
Total Regulatory Assets	545	11,247
Pipeline Supplier Service Charges
Regulatory Assets [Line Items]
Total Regulatory Assets	4,192	5,441
Pipeline Integrity Cost
Regulatory Assets [Line Items]
Total Regulatory Assets	4,544	3,431
AFUDC - Equity Related Deferrals
Regulatory Assets [Line Items]
Total Regulatory Assets	11,188	10,781
Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 2,339	$ 1,876

REGULATORY ASSETS & REGULATOR45

REGULATORY ASSETS & REGULATORY LIABILITIES 2 (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 62,461	$ 41,899
Excess Plant Removal Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	34,040	35,940
Conservation Incentive Program Payable
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	18,616	4,700
Societal Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	9,805	0
Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 0	$ 1,259

PENSION AND OTHER POSTRETIREM46

PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($)	1 Months Ended	3 Months Ended		9 Months Ended		12 Months Ended
	Jan. 31, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Pension Benefits
Net periodic benefit cost [Abstract]
Service Cost		$ 1,334,000	$ 813,000	$ 4,003,000	$ 3,383,000
Interest Cost		2,792,000	2,661,000	8,376,000	8,051,000
Expected Return on Plan Assets		(3,697,000)	(3,262,000)	(11,092,000)	(9,792,000)
Amortizations:
Prior Service Cost		53,000	45,000	159,000	131,000
Actuarial Loss		2,652,000	1,398,000	7,956,000	4,250,000
Net Periodic Benefit Cost		3,134,000	1,655,000	9,402,000	6,023,000
Capitalized Benefit Cost		(1,216,000)	(577,000)	(3,649,000)	(2,285,000)
Deferred Benefit Cost		(341,000)	0	(666,000)	0
Total Net Periodic Benefit Expense		1,577,000	1,078,000	5,087,000	3,738,000
Contributions	$ 15,000,000					$ 0
Other Postretirement Benefits
Net periodic benefit cost [Abstract]
Service Cost		279,000	168,000	837,000	668,000
Interest Cost		743,000	659,000	2,230,000	2,139,000
Expected Return on Plan Assets		(748,000)	(688,000)	(2,245,000)	(2,062,000)
Amortizations:
Prior Service Cost		152,000	38,000	456,000	114,000
Actuarial Loss		336,000	245,000	1,007,000	731,000
Net Periodic Benefit Cost		762,000	422,000	2,285,000	1,590,000
Capitalized Benefit Cost		(264,000)	(42,000)	(792,000)	(460,000)
Deferred Benefit Cost		(89,000)	0	(168,000)	0
Total Net Periodic Benefit Expense		$ 409,000	$ 380,000	1,325,000	$ 1,130,000
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)	9 Months Ended
LINES OF CREDIT (Details)	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)
Line of Credit Facility [Line Items]
Total Facility	$ 610,000,000
Usage	360,100,000
Available Liquidity	$ 249,900,000
Weighted average borrowing cost	1.03%	0.83%
Average borrowings outstanding during the period	$ 310,800,000	$ 291,600,000
Maximum amounts outstanding during the period	$ 432,400,000	$ 390,700,000
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	89,900,000
Available Liquidity	120,100,000
South Jersey Gas Company \| Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility	200,000,000
Usage	89,900,000
Available Liquidity	110,100,000
Letters of credit outstanding	600,000
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
South Jersey Industries Inc
Line of Credit Facility [Line Items]
Total Facility	400,000,000
Usage	270,200,000
Available Liquidity	129,800,000
South Jersey Industries Inc \| Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility	400,000,000
Usage	270,200,000
Available Liquidity	129,800,000
Letters of credit outstanding	$ 8,100,000

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details) $ in Thousands	1 Months Ended	9 Months Ended
COMMITMENTS AND CONTINGENCIES (Details) $ in Thousands	May. 31, 2012	Sep. 30, 2015USD ($)unions	Dec. 31, 2014USD ($)sites
Guarantees [Abstract]
Liability recorded related to guarantees		$ 600
Maximum amount of obligation under guarantee contracts		4,200
Notes receivable - affiliate		$ 13,765	$ 14,657
Collective bargaining agreements [Abstract]
Percentage of personnel represented by collective bargaining agreements		44.00%
Number of unions (in unions) \| unions		2
Letter of credit provided		$ 610,000
Pending litigation [Abstract]
Estimated litigation liability		3,200	$ 2,900
Environmental remediation costs [Abstract]
Number of sites for environmental cleanup (in number of sites) \| sites			12
South Jersey Gas Company
Collective bargaining agreements [Abstract]
Letter of credit provided		210,000
South Jersey Gas Company \| Revolving Credit Facility
Collective bargaining agreements [Abstract]
Letter of credit provided		200,000
Letters of credit outstanding		600
Standby Letter of Credit
Collective bargaining agreements [Abstract]
Letter of credit provided		8,100
Letter of Credit, Separate Facility
Collective bargaining agreements [Abstract]
Letter of credit provided		$ 87,600
Energenic
Guarantees [Abstract]
Equity interest		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
LVE Energy Partners
Guarantees [Abstract]
Notes receivable - affiliate		8,200
Parental Guarantee
Guarantees [Abstract]
Guaranteed amount		$ 5,700
Guarantee Expiration Period		2 years

DERIVATIVE INSTRUMENTS (Details

DERIVATIVE INSTRUMENTS (Details) dts in Millions, MWh in Millions	Sep. 30, 2015MWhdts
Basis and Index Related Purchase and Sales Contracts
Derivative [Line Items]
Outstanding derivative contracts notional amount	226.3
Natural Gas (in MMdts) \| Derivative Transaction Type, Purchase
Derivative [Line Items]
Outstanding derivative contracts notional amount	55.5
Natural Gas (in MMdts) \| Derivative Transaction Type, Sale
Derivative [Line Items]
Outstanding derivative contracts notional amount	44.8
Electricity (in MMmwh) \| Derivative Transaction Type, Purchase
Derivative [Line Items]
Outstanding derivative contracts notional amount \| MWh	2.9
Electricity (in MMmwh) \| Derivative Transaction Type, Sale
Derivative [Line Items]
Outstanding derivative contracts notional amount \| MWh	2.8

DERIVATIVE INSTRUMENTS 2 (Detai

DERIVATIVE INSTRUMENTS 2 (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	$ 77,674	$ 99,273
Fair value Derivative Liabilities	121,801	140,402
Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	77,674	99,273
Fair value Derivative Liabilities	121,801	140,402
Commodity Contract
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	77,674	99,273
Fair value Derivative Liabilities	0	0
Commodity Contract \| Not Designated as Hedging Instrument \| Derivatives-Energy Related-Current
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	60,536	85,368
Fair value Derivative Liabilities	86,793	109,744
Commodity Contract \| Not Designated as Hedging Instrument \| Derivatives-Energy Related-NonCurrent
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	17,138	13,905
Fair value Derivative Liabilities	23,490	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	$ 11,518	$ 10,732

DERIVATIVE INSTRUMENTS 3 (Detai

DERIVATIVE INSTRUMENTS 3 (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	$ 77,674	$ 99,273
Offsetting Derivative Liabilities [Abstract]
Gross amount offset in the balance sheet	121,801	140,402
Commodity Contract
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	77,674	99,273
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	77,674	99,273
Gross amounts not offset in the balance sheet, Financial Instruments	(30,785)	(39,747)
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0	0
Net amount	46,889	59,526
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(110,283)	(129,670)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(110,283)	(129,670)
Gross amounts not offset in the balance sheet, Financial Instruments	30,785	39,747
Gross amounts not offset in the balance sheet, Cash Collateral Posted	30,856	53,897
Net amount	(48,642)	(36,026)
Other Contract
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(11,518)	(10,732)
Gross amount offset in the balance sheet	0	0
Net amounts of assets/liabilities in balance sheet	(11,518)	(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	$ (11,518)	$ (10,732)

DERIVATIVE INSTRUMENTS 4 (Detai

DERIVATIVE INSTRUMENTS 4 (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
DERIVATIVE INSTRUMENTS 4 (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$ 0	$ 0	$ 0	$ 0
Losses reclassified from AOCL into income	(93)	(112)	(303)	(336)
Gains (losses) recognized in income on ineffective portion	0	0	0	0
Total	(12,427)	(1,431)	(4,206)	(30,532)
Net realized gains (losses), derivative instruments, energy-related contracts	(1,600)	(1,200)	(6,400)	2,400
Fair value derivative instruments with credit-risk-related features	44,300		44,300
Additional collateral, aggregate fair value	39,800		39,800
Not Designated as Hedging Instrument
Interest Rate Contracts:
Gain (losses) on energy related commodity contracts	(11,992)	(1,633)	(4,014)	(30,429)
Gain (losses) on interest rate contracts	$ (435)	$ 202	$ (192)	$ (103)

FAIR VALUE OF FINANCIAL ASSET53

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period	$ (2,544)	$ (4,769)	$ (5,608)	$ 8,095
Other changes in fair value from continuing and new contracts, net	(10,725)	(423)	(12,787)	(14,799)
Transfers in/(out) of Level 3	0		2,054
Settlements	(1,396)	2,493	1,676	4,005
Balance at end of period	(14,665)	$ (2,699)	(14,665)	$ (2,699)
Fair Value, Measurements, Recurring
Assets
Available-for-Sale Securities	14,371		14,371		$ 8,922
Derivatives - Energy Related Assets	77,674		77,674		99,273
Total Assets	92,045		92,045		108,195
Liabilities
Derivatives - Energy Related Liabilities	110,283		110,283		129,670
Derivatives - Other	11,518		11,518		10,732
Total Liabilities	121,801		121,801		140,402
Fair Value, Measurements, Recurring \| Level 1
Assets
Available-for-Sale Securities	5,759		5,759		5,952
Derivatives - Energy Related Assets	9,991		9,991		21,675
Total Assets	15,750		15,750		27,627
Liabilities
Derivatives - Energy Related Liabilities	34,536		34,536		49,009
Derivatives - Other	0		0		0
Total Liabilities	34,536		34,536		49,009
Fair Value, Measurements, Recurring \| Level 2
Assets
Available-for-Sale Securities	8,612		8,612		2,970
Derivatives - Energy Related Assets	27,351		27,351		43,093
Total Assets	35,963		35,963		46,063
Liabilities
Derivatives - Energy Related Liabilities	20,750		20,750		40,548
Derivatives - Other	11,518		11,518		10,732
Total Liabilities	32,268		32,268		51,280
Fair Value, Measurements, Recurring \| Level 3
Assets
Available-for-Sale Securities	0		0		0
Derivatives - Energy Related Assets	40,332		40,332		34,505
Total Assets	40,332		40,332		34,505
Liabilities
Derivatives - Energy Related Liabilities	54,997		54,997		40,113
Derivatives - Other	0		0		0
Total Liabilities	$ 54,997		$ 54,997		$ 40,113

FAIR VALUE OF FINANCIAL ASSET54

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES, LEVEL THREE INPUTS (Details) - Forward Contracts - Fair Value, Inputs, Level 3 $ in Thousands	Sep. 30, 2015USD ($)$ / decatherm	Dec. 31, 2014USD ($)$ / decatherm
Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	$ 19,113	$ 26,485
Liabilities	35,812	33,882
Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	21,219	8,020
Liabilities	$ 19,185	$ 6,231
Minimum \| Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) \| $ / decatherm	(0.95)	(2.04)
Maximum \| Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) \| $ / decatherm	9.83	7.83
Weighted Average \| Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) \| $ / decatherm	0.45	(0.30)
On-Peak \| Minimum \| Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	8.47%	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	56.44%	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	91.53%	91.94%
Off-Peak \| Weighted Average \| Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	43.56%	44.03%

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details) - USD ($)	1 Months Ended	9 Months Ended
LONG-TERM DEBT (Details) - USD ($)	Sep. 30, 2015	Sep. 30, 2015	Sep. 30, 2014	Aug. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.50%	7.50%
Proceeds from Issuance of Long-Term Debt		$ 80,000,000	$ 329,000,000
Line of Credit Facility, Maximum Borrowing Capacity	$ 610,000,000	610,000,000
Long-term Debt	1,015,300,000	1,015,300,000				$ 1,009,400,000
South Jersey Gas Company
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	210,000,000	210,000,000
South Jersey Gas Company \| Line of Credit
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	200,000,000	200,000,000
Loans Payable \| South Jersey Gas Company \| Line of Credit
Debt Instrument [Line Items]
Proceeds from Issuance of Long-Term Debt	80,000,000
Long-term Debt	139,000,000	139,000,000
Series A Notes Due 2015, 2.39% \| Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Repurchase Face Amount					$ 64,000,000
Debt Instrument, Interest Rate, Stated Percentage					2.39%
Series Due 2015, 5.387% \| Medium-term Notes \| South Jersey Gas Company
Debt Instrument [Line Items]
Debt Instrument, Repurchase Face Amount				$ 10,000,000
Debt Instrument, Interest Rate, Stated Percentage				5.387%
September 2008 Variable Rate Demand Bonds \| South Jersey Gas Company
Debt Instrument [Line Items]
Extinguishment of Debt, Amount	100,000
Debt Instrument, Face Amount	$ 25,000,000	$ 25,000,000

ACCUMULATED OTHER COMPREHENSI56

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		$ (30,151)		$ (30,258)
Other comprehensive income before reclassifications		(276)		(227)
Amounts reclassified from AOCL		55		113
Other Comprehensive Loss - Net of Tax	[1]	(221)	$ (484)	(114)	$ (236)
Ending balance		$ (30,372)		$ (30,372)
Combined statutory tax rate		40.00%	41.00%	40.00%	41.00%
Postretirement Liability Adjustment
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		$ (27,663)		$ (27,663)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL		0		0
Other Comprehensive Loss - Net of Tax		0		0
Ending balance		(27,663)		(27,663)
Unrealized Gain (Loss) on Derivatives-Other
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(2,331)		(2,450)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL		52		171
Other Comprehensive Loss - Net of Tax		52		171
Ending balance		(2,279)		(2,279)
Unrealized Gain (Loss) on Available-for-Sale Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(51)		(75)
Other comprehensive income before reclassifications		(276)		(227)
Amounts reclassified from AOCL		99		74
Other Comprehensive Loss - Net of Tax		(177)		(153)
Ending balance		(228)		(228)
Other Comprehensive Income (Loss) of Affiliated Companies
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(106)		(70)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL		(96)		(132)
Other Comprehensive Loss - Net of Tax		(96)		(132)
Ending balance		$ (202)		$ (202)

[1]	For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.

ACCUMULATED OTHER COMPREHENSI57

ACCUMULATED OTHER COMPREHENSIVE LOSS 2 (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	$ 8,107	$ 6,768	$ 24,182	$ 20,698
Other Income	(2,241)	(3,419)	(7,522)	(9,972)
Equity in Loss of Affiliated Companies	2,581	5,139	17,970	3,756
Income Taxes	(10,968)	(8,325)	2,366	(5,966)
Losses from reclassifications for the period net of tax	12,532	$ 4,276	(54,662)	$ (53,636)
Reclassification out of Accumulated Other Comprehensive Income
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Losses from reclassifications for the period net of tax	55		113
Reclassification out of Accumulated Other Comprehensive Income \| Unrealized Gain (Loss) on Derivatives-Other
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	93		303
Income Taxes	(41)		(132)
Losses from reclassifications for the period net of tax	52		171
Reclassification out of Accumulated Other Comprehensive Income \| Unrealized Loss on Available-for-Sale Securities
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Other Income	168		127
Income Taxes	(69)		(53)
Losses from reclassifications for the period net of tax	99		74
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	(158)		(218)
Income Taxes	62		86
Losses from reclassifications for the period net of tax	$ (96)		$ (132)

SUBSEQUENT EVENT (Details)

SUBSEQUENT EVENT (Details)	Oct. 31, 2015USD ($)
Subsequent Event \| Unsecured Debt \| Term Loan Due October 2020
Subsequent Event [Line Items]
Debt Instrument, Face Amount	$ 50,000,000