South Jersey Industries (SJIIU) 10-Q 7 Aug 15 2015 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Aug. 03, 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	Jun. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		68,542,760

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)$ / sharesshares	Jun. 30, 2014USD ($)$ / sharesshares	Jun. 30, 2015USD ($)$ / sharesshares	Jun. 30, 2014USD ($)$ / sharesshares
Operating Revenues:
Utility	$ 75,294	$ 68,903	$ 341,824	$ 279,232
Nonutility	102,416	64,368	218,838	204,240
Total Operating Revenues	177,710	133,271	560,662	483,472
Cost of Sales - (Excluding depreciation)
- Utility	24,901	24,623	169,875	127,700
- Nonutility	66,044	54,324	162,777	179,385
Operations	33,802	30,652	75,663	70,002
Maintenance	3,928	3,181	7,926	6,440
Depreciation	17,430	15,495	34,249	30,486
Energy and Other Taxes	1,265	1,241	3,461	3,194
Total Operating Expenses	147,370	129,516	453,951	417,207
Operating Income	30,340	3,755	106,711	66,265
Other Income and Expense	3,040	4,185	5,281	6,553
Interest Charges	(7,474)	(6,846)	(16,075)	(13,930)
Income Before Income Taxes	25,906	1,094	95,917	58,888
Income Taxes	3,279	9,510	(13,334)	(2,359)
Equity in Loss of Affiliated Companies	(15,844)	(903)	(15,389)	1,383
Income from Continuing Operations	13,341	9,701	67,194	57,912
Loss from Discontinued Operations - (Net of tax benefit)	(74)	(80)	(350)	(393)
Net Income	$ 13,267	$ 9,621	$ 66,844	$ 57,519
Basic Earnings Per Common Share:
Continuing Operations (in dollars per share) | $ / shares	$ 0.19	$ 0.15	$ 0.98	$ 0.88
Discontinued Operations (in dollars per share) | $ / shares	0	0	0	0
Basic Earnings Per Common Share (in dollars per share) | $ / shares	$ 0.19	$ 0.15	$ 0.98	$ 0.88
Average Shares of Common Stock Outstanding - Basic (in shares) | shares	68,467	65,926	68,432	65,728
Diluted Earnings Per Common Share:
Continuing Operations (in dollars per share) | $ / shares	$ 0.19	$ 0.15	$ 0.98	$ 0.88
Discontinued Operations (in dollars per share) | $ / shares	0	0	0	0
Diluted Earnings Per Common Share (in dollars per share) | $ / shares	$ 0.19	$ 0.15	$ 0.98	$ 0.88
Average Shares of Common Stock Outstanding - Diluted (in shares) | shares	68,653	66,074	68,636	65,880
Dividends Declared Per Common Share (in dollars per share) | $ / shares	$ 0.25	$ 0.24	$ 0.50	$ 0.47

CONDENSED CONSOLIDATED STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Statement of Comprehensive Income [Abstract]
Net Income		$ 13,267	$ 9,621	$ 66,844	$ 57,519
Other Comprehensive Income, Net of Tax:
Unrealized (Loss) Gain on Available-for-Sale Securities	[1]	(64)	154	24	216
Unrealized Gain on Derivatives - Other	[1]	111	66	119	132
Other Comprehensive Income (Loss) of Affiliated Companies	[1]	59	(82)	(36)	(100)
Other Comprehensive Income - Net of Tax	[1]	106	138	107	248
Comprehensive Income		$ 13,373	$ 9,759	$ 66,951	$ 57,767
[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)	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Statement of Comprehensive Income [Abstract]
Combined statutory tax rate	40.00%	41.00%

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Statement of Cash Flows [Abstract]
Net Cash Provided by Operating Activities	$ 102,059	$ 89,669
Cash Flows from Investing Activities:
Capital Expenditures	(141,585)	(134,945)
Purchase of Available for Sale Securities	(6,059)	0
Net Proceeds from Sale of Restricted Investments in Margin Account	12,581	3,333
Investment in Long-Term Receivables	(3,381)	(3,410)
Proceeds from Long-Term Receivables	2,040	3,536
Notes Receivable	(9,887)	0
Purchase of Company Owned Life Insurance	(765)	(526)
Investment in Affiliate	(1,766)	0
Advances on Notes Receivable - Affiliate	(1,514)	(1,922)
Repayment of Notes Receivable - Affiliate	4,612	5,639
Net Cash Used in Investing Activities	(145,724)	(128,295)
Cash Flows from Financing Activities:
Net Borrowings from (Repayments of) Short-Term Credit Facilities	120,300	(147,200)
Proceeds from Issuance of Long-Term Debt	0	189,000
Principal Repayments of Long-Term Debt	(64,000)	0
Payments for Issuance of Long-Term Debt	0	(1,204)
Dividends on Common Stock	(17,192)	(15,510)
Proceeds from Sale of Common Stock	3,596	17,119
Net Cash Provided by Financing Activities	42,704	42,205
Net (Decrease) Increase in Cash and Cash Equivalents	(961)	3,579
Cash and Cash Equivalents at Beginning of Period	4,171	3,818
Cash and Cash Equivalents at End of Period	$ 3,210	$ 7,397

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands		Jun. 30, 2015	Dec. 31, 2014
Property, Plant and Equipment:
Utility Plant, at original cost		$ 2,101,634	$ 2,002,966
Accumulated Depreciation		(426,190)	(413,597)
Nonutility Property and Equipment, at cost		654,129	622,079
Accumulated Depreciation		(92,195)	(77,345)
Property, Plant and Equipment - Net		2,237,378	2,134,103
Investments:
Available-for-Sale Securities		15,121	8,922
Restricted		53,752	65,451
Investment in Affiliates		51,970	68,351
Total Investments		120,843	142,724
Current Assets:
Cash and Cash Equivalents		3,210	4,171
Accounts Receivable		257,216	251,892
Unbilled Revenues		25,291	62,608
Provision for Uncollectibles		(10,182)	(7,910)
Notes Receivable		9,887	0
Notes Receivable - Affiliate		12,059	14,657
Natural Gas in Storage, average cost		47,233	63,246
Materials and Supplies, average cost		2,123	2,125
Deferred Income Taxes - Net		60,052	57,748
Prepaid Taxes		20,460	14,106
Derivatives - Energy Related Assets		73,879	85,368
Other Prepayments and Current Assets		26,897	18,686
Total Current Assets		528,125	566,697
Regulatory and Other Noncurrent Assets:
Regulatory Assets		335,182	357,160
Derivatives - Energy Related Assets		19,204	13,905
Unamortized Debt Issuance Costs		9,106	9,795
Notes Receivable - Affiliate		36,300	36,799
Contract Receivables		23,584	19,236
Notes Receivable		7,882	7,882
Other		61,342	61,124
Total Regulatory and Other Noncurrent Assets		492,600	505,901
Total Assets		3,378,946	3,349,425
Equity:
Common Stock		85,598	85,418
Premium on Common Stock		443,141	438,384
Treasury Stock (at par)		(287)	(330)
Accumulated Other Comprehensive Loss	[1]	(30,151)	(30,258)
Retained Earnings		471,676	439,218
Total Equity		969,977	932,432
Long-Term Debt		859,491	859,491
Total Capitalization		1,829,468	1,791,923
Current Liabilities:
Notes Payable		366,000	245,700
Current Portion of Long-Term Debt		85,909	149,909
Accounts Payable		193,719	272,998
Customer Deposits and Credit Balances		19,191	17,958
Environmental Remediation Costs		41,704	30,430
Taxes Accrued		3,010	2,328
Derivatives - Energy Related Liabilities		92,914	109,744
Dividends Payable		17,205	0
Interest Accrued		7,122	7,088
Pension Benefits		1,515	1,550
Other Current Liabilities		6,261	12,480
Total Current Liabilities		834,550	850,185
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net		355,219	344,520
Investment Tax Credits		74	149
Pension and Other Postretirement Benefits		100,358	115,373
Environmental Remediation Costs		87,440	97,742
Asset Retirement Obligations		42,826	42,502
Derivatives - Energy Related Liabilities		21,889	19,926
Derivatives - Other		9,779	10,732
Regulatory Liabilities		64,655	41,899
Finance Obligation		19,170	19,659
Other		13,518	14,815
Total Deferred Credits and Other Noncurrent Liabilities		$ 714,928	$ 707,317
Commitments and Contingencies
Total Capitalization and Liabilities		$ 3,378,946	$ 3,349,425
[1]	For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	6 Months Ended
	Jun. 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 both the three months ended June 30, 2015 and 2014 , and $0.8 million and $0.6 million for the six months ended June 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 six months ended June 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 six months ended June 30, 2015 or 2014 . As of both June 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 June 30, 2015 and December 31, 2014 , SJI held 229,536 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.

STOCK-BASED COMPENSATION PLAN

STOCK-BASED COMPENSATION PLAN	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
STOCK-BASED COMPENSATION PLAN	STOCK-BASED COMPENSATION PLAN: Under the Amended and Restated 1997 Stock-Based Compensation Plan, shares may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. This plan terminated on January 26, 2015. On January 23, 2015, the Board of Directors approved a new stock-based compensation plan. The new plan was approved by shareholders on April 30, 2015. No options were granted or outstanding during the six months ended June 30, 2015 and 2014 . No stock appreciation rights have been issued under the plans. During the six months ended June 30, 2015 and 2014 , SJI granted 159,416 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 between 0% to 200% of the original share units granted. In 2015, SJI also granted time-based shares of restricted stock, one-third of which vests annually over a three -year period and is limited to 100% payout. 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 47,824 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 six months ended June 30, 2015 and 2014 , SJI granted 25,398 and 23,220 restricted shares, respectively, to Directors. Shares issued to Directors vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest. The following table summarizes the nonvested restricted stock awards outstanding at June 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 45,593 $ 22.19 21.1 % 0.40 % 2013 - EPS 45,593 $ 25.59 N/A N/A 2014 - TSR 51,323 $ 21.31 20.0 % 0.80 % 2014 - EPS 51,323 $ 27.22 N/A N/A 2015 - TSR 34,696 $ 26.31 16.0 % 1.10 % 2015 - EPS, ROE, Time 89,232 $ 29.47 N/A N/A Directors - 2015 25,398 $ 29.34 N/A N/A Expected volatility is based on the actual volatility of SJI’s share price over the preceding three -year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three -year term of the Officers’ and other key employees’ restricted shares. As notional dividend equivalents are credited to the holders during the three -year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant. The following table summarizes the total stock-based compensation cost for the three and six months ended June 30, 2015 and 2014 (in thousands): Three Months Ended Six Months Ended 2015 2014 2015 2014 Officers & Key Employees $ 511 $ 586 $ 1,310 $ 1,167 Directors 186 158 372 316 Total Cost 697 744 1,682 1,483 Capitalized (87 ) (70 ) (178 ) (140 ) Net Expense $ 610 $ 674 $ 1,504 $ 1,343 As of June 30, 2015 , there was $4.6 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the Plan. That cost is expected to be recognized over a weighted average period of 2.0 years. The following table summarizes information regarding restricted stock award activity during the six months ended June 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 159,416 25,398 $ 28.69 Cancelled/Forfeited (65,532 ) — $ 26.56 Vested — (23,220 ) $ 27.26 Nonvested Shares Outstanding, June 30, 2015 317,760 25,398 $ 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 six months ended June 30, 2015 and 2014 , SJI granted 25,398 and 23,220 shares to its Directors at a market value of $0.7 million and $0.6 million , respectively. The Company has a policy of issuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of the Plan. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash. At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods. These deferred shares are included in Treasury Stock on the condensed consolidated balance sheets.

DISCONTINUED OPERATIONS AND AFF

DISCONTINUED OPERATIONS AND AFFILIATIONS	6 Months Ended
	Jun. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
DISCONTINUED OPERATIONS AND AFFILATIONS	DISCONTINUED OPERATIONS AND AFFILATIONS: Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (EMI), an SJI subsidiary, which previously operated a fuel oil business. Morie is the former sand mining and processing subsidiary of EMI. EMI sold the common stock of Morie in 1996. SJI conducts tests annually to estimate the environmental remediation costs for these properties. Summarized operating results of the discontinued operations for the three and six months ended June 30 , 2015 and 2014, were (in thousands, except per share amounts): Three Months Ended Six Months Ended 2015 2014 2015 2014 Loss Before Income Taxes: Sand Mining $ (17 ) $ (103 ) $ (364 ) $ (483 ) Fuel Oil (97 ) (20 ) (163 ) (122 ) Income Tax Benefits 40 43 177 212 Loss from Discontinued Operations — Net $ (74 ) $ (80 ) $ (350 ) $ (393 ) Earnings (Loss) Per Common Share from Discontinued Operations — Net: Basic and Diluted $ — $ — $ — $ — 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 expects to construct an approximately 100 -mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, estimated to be completed in 2017. During the first six months of 2015 and 2014, the Company received net repayments from unconsolidated affiliates of $1.3 million and $3.7 million , respectively. As of June 30, 2015 and December 31, 2014 , the outstanding balance of Notes Receivable – Affiliate was $48.4 million and $51.5 million , respectively. As of June 30, 2015, approximately $39.2 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 $9.2 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 June 30, 2015 , the Company had a net asset of approximately $51.1 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 June 30, 2015 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $100.3 million plus the guarantees discussed in Note 11.

COMMON STOCK

COMMON STOCK	6 Months Ended
	Jun. 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 116,884 Stock-Based Compensation Plan 26,338 Ending Balance, June 30 68,478,082 The par value ( $1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $4.8 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 186,147 and 148,664 for the three months ended June 30, 2015 and 2014 , respectively, and 203,455 and 151,556 for the six months ended June 30, 2015 and 2014, respectively. These shares relate to SJI's restricted stock as discussed in Note 2. DIVIDEND REINVESTMENT PLAN (DRP) —The Company offers a DRP which allows participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases. Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $3.6 million and $17.1 million of equity capital through the DRP during the six months ended June 30, 2015 and 2014 , respectively.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	6 Months Ended
	Jun. 30, 2015
Financial Instruments, Owned, at Fair Value [Abstract]
FINANCIAL INSTRUMENTS	FINANCIAL INSTRUMENTS: RESTRICTED INVESTMENTS — In accordance with the terms of certain Marina and SJG loan agreements, unused proceeds are required to be escrowed pending approval of construction expenditures. As of June 30, 2015 and December 31, 2014 , the escrowed proceeds, 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 June 30, 2015 and December 31, 2014 , the balances in these accounts totaled $51.1 million and $63.7 million , respectively. The carrying amounts of the Restricted Investments approximate their fair values at June 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 three months ended June 30, 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 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 June 30, 2015 , the Company, through its investment in Energenic, had a remaining net asset of approximately $2.2 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. LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources. The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest. The carrying amounts of such loans were $14.0 million and $15.0 million as of June 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 $1.1 million and $1.3 million as of June 30, 2015 and December 31, 2014 , respectively. The annualized amortization to interest is not material to the Company’s condensed consolidated financial statements. The carrying amounts of these receivables approximate their fair value at June 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 June 30, 2015 , approximately $8.0 million , or 8.6% , 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 June 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 $19.2 million and $19.7 million , net of amortization, within Finance Obligation on the condensed consolidated balance sheets at June 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 June 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 June 30, 2015 and December 31, 2014 , were $986.4 million and $1,058.5 million , respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of June 30, 2015 and December 31, 2014 , were $945.4 million and $1,009.4 million , respectively.

SEGMENTS OF BUSINESS

SEGMENTS OF BUSINESS	6 Months Ended
	Jun. 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. 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 Six Months Ended 2015 2014 2015 2014 Operating Revenues: Gas Utility Operations $ 75,812 $ 69,159 $ 343,470 $ 279,704 Energy Group: Wholesale Energy Operations 33,276 (2,936 ) 68,621 32,436 Retail Gas and Other Operations 18,065 24,875 56,143 76,381 Retail Electric Operations 36,186 27,879 65,963 68,272 Subtotal Energy Group 87,527 49,818 190,727 177,089 Energy Services: On-Site Energy Production 15,136 14,397 28,708 25,743 Appliance Service Operations 2,699 2,637 5,056 5,291 Subtotal Energy Services 17,835 17,034 33,764 31,034 Corporate & Services 7,765 6,452 16,851 14,323 Subtotal 188,939 142,463 584,812 502,150 Intersegment Sales (11,229 ) (9,192 ) (24,150 ) (18,678 ) Total Operating Revenues $ 177,710 $ 133,271 $ 560,662 $ 483,472 Three Months Ended Six Months Ended 2015 2014 2015 2014 Operating Income (Loss): Gas Utility Operations $ 11,961 $ 9,005 $ 85,150 $ 72,445 Energy Group: Wholesale Energy Operations 15,158 (8,468 ) 15,488 (10,123 ) Retail Gas and Other Operations 153 (191 ) 3,240 1,777 Retail Electric Operations 174 (840 ) (8 ) (894 ) Subtotal Energy Group 15,485 (9,499 ) 18,720 (9,240 ) Energy Services: On-Site Energy Production 2,177 3,636 1,695 2,376 Appliance Service Operations 247 357 195 262 Subtotal Energy Services 2,424 3,993 1,890 2,638 Corporate and Services 470 256 951 422 Total Operating Income $ 30,340 $ 3,755 $ 106,711 $ 66,265 Depreciation and Amortization: Gas Utility Operations $ 14,239 $ 12,757 $ 28,406 $ 25,433 Energy Group: Wholesale Energy Operations 15 46 47 86 Retail Gas and Other Operations 20 20 40 42 Subtotal Energy Group 35 66 87 128 Energy Services: On-Site Energy Production 7,457 6,165 14,508 11,940 Appliance Service Operations 73 67 147 134 Subtotal Energy Services 7,530 6,232 14,655 12,074 Corporate and Services 458 235 700 454 Total Depreciation and Amortization $ 22,262 $ 19,290 $ 43,848 $ 38,089 Interest Charges: Gas Utility Operations $ 5,113 $ 4,292 $ 10,303 $ 8,634 Energy Group: Wholesale Energy Operations (112 ) (5 ) 130 116 Retail Gas and Other Operations 47 68 120 194 Subtotal Energy Group (65 ) 63 250 310 Energy Services: On-Site Energy Production 1,661 2,147 3,976 4,275 Corporate and Services 2,939 1,790 5,927 3,640 Subtotal 9,648 8,292 20,456 16,859 Intersegment Borrowings (2,174 ) (1,446 ) (4,381 ) (2,929 ) Total Interest Charges $ 7,474 $ 6,846 $ 16,075 $ 13,930 Three Months Ended Six Months Ended 2015 2014 2015 2014 Income Taxes: Gas Utility Operations $ 3,292 $ 2,379 29,464 24,906 Energy Group: Wholesale Energy Operations 5,986 (2,628 ) 6,853 (3,181 ) Retail Gas and Other Operations 92 80 1,668 1,016 Retail Electric Operations 71 (343 ) (3 ) (365 ) Subtotal Energy Group 6,149 (2,891 ) 8,518 (2,530 ) Energy Services: On-Site Energy Production (12,861 ) (9,404 ) (24,908 ) (20,429 ) Appliance Service Operations 105 211 97 188 Subtotal Energy Services (12,756 ) (9,193 ) (24,811 ) (20,241 ) Corporate and Services 36 195 163 224 Total Income Taxes $ (3,279 ) $ (9,510 ) $ 13,334 $ 2,359 Property Additions: Gas Utility Operations $ 62,175 $ 59,067 $ 105,501 $ 91,598 Energy Group: Wholesale Energy Operations 375 8 379 10 Retail Gas and Other Operations 392 229 1,121 397 Subtotal Energy Group 767 237 1,500 407 Energy Services: On-Site Energy Production 26,040 16,426 30,421 25,575 Appliance Service Operations 212 6 328 6 Subtotal Energy Services 26,252 16,432 30,749 25,581 Corporate and Services 537 803 1,601 1,581 Total Property Additions $ 89,731 $ 76,539 $ 139,351 $ 119,167 June 30, 2015 December 31, 2014 Identifiable Assets: Gas Utility Operations $ 2,266,233 $ 2,185,672 Energy Group: Wholesale Energy Operations 269,922 366,119 Retail Gas and Other Operations 35,801 53,073 Retail Electric Operations 47,730 23,682 Subtotal Energy Group 353,453 442,874 Energy Services: On-Site Energy Production 685,765 675,937 Appliance Service Operations 3,425 3,105 Subtotal Energy Services 689,190 679,042 Discontinued Operations 1,600 1,758 Corporate and Services 571,333 527,691 Intersegment Assets (502,863 ) (487,612 ) Total Identifiable Assets $ 3,378,946 $ 3,349,425

RATES AND REGULATORY ACTIONS

RATES AND REGULATORY ACTIONS	6 Months Ended
	Jun. 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 January 2015, SJG filed a petition with the BPU seeking to continue offering energy efficiency programs through June 2018 with a proposed total budget of $56.0 million and with the same rate recovery mechanism that exists for its current energy efficiency programs. This petition is currently pending. In April 2015, SJG filed a petition requesting to increase annual revenues from base rates by $4.6 million to reflect the roll-in of investments made through June 2015 under its Storm Hardening and Reliability Program (“SHARP”), with rates to become effective on October 1, 2015. This petition is currently pending. 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 Basic Gas Supply Service (“BGSS”) and Conservation Incentive Program (“CIP”) rate adjustment petition, requesting 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. This petition is currently pending. Also 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. The various 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	6 Months Ended
	Jun. 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): June 30, 2015 December 31, 2014 Environmental Remediation Costs: Expended - Net $ 29,145 $ 29,540 Liability for Future Expenditures 125,769 124,308 Deferred Asset Retirement Obligation Costs 31,799 31,584 Deferred Pension and Other Postretirement Benefit Costs 99,040 99,040 Deferred Gas Costs - Net 20,194 32,202 Societal Benefit Costs Receivable — 385 Deferred Interest Rate Contracts 6,615 7,325 Energy Efficiency Tracker 852 11,247 Pipeline Supplier Service Charges 4,608 5,441 Pipeline Integrity Cost 3,851 3,431 AFUDC - Equity Related Deferrals 11,330 10,781 Other Regulatory Assets 1,979 1,876 Total Regulatory Assets $ 335,182 $ 357,160 DEFERRED GAS COSTS - NET - Over/under collections of gas costs are monitored through SJG's Basic Gas Supply Service (BGSS) mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. The reduction in deferred gas costs from December 31, 2014 was due to gas costs recovered from customers exceeding the actual cost of the commodity incurred during the first six months of 2015 as a result of lower natural gas prices. SJG's BGSS mechanism is designed to over-collect gas costs during the winter season when usage is highest. ENERGY EFFICIENCY TRACKER - This regulatory asset primarily represents energy efficiency measures installed in customer homes and businesses. The decrease from December 31, 2014 is due to higher recoveries in the first six months of 2015 resulting from extremely cold weather. Regulatory Liabilities consisted of the following items (in thousands): June 30, 2015 December 31, 2014 Excess Plant Removal Costs $ 34,701 $ 35,940 Conservation Incentive Program Payable 17,255 4,700 Societal Benefit Costs 12,699 — Other Regulatory Liabilities — 1,259 Total Regulatory Liabilities $ 64,655 $ 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 six months of 2015 resulting in a payable. This is primarily the result of extremely cold weather experienced in the region. SOCIETAL BENEFIT COSTS (SBC) - This regulatory liability primarily represents the excess recoveries over the expenses incurred under the New Jersey Clean Energy Program which is a mechanism designed to recover costs associated with energy efficiency and renewable energy programs. The change from a $0.4 million regulatory asset to a $12.7 million regulatory liability is due to current SBC rates which are producing revenue greater than SBC expenses. In July 2014, SJG made its annual 2014-2015 SBC filing requesting a decrease in SBC revenues, in part, to avoid this liability. The petition was approved and new rates went into effect on June 1, 2015.

PENSION AND OTHER POSTRETIREMEN

PENSION AND OTHER POSTRETIREMENT BENEFITS	6 Months Ended
	Jun. 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 six months ended June 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 Six Months Ended 2015 2014 2015 2014 Service Cost $ 1,225 $ 1,285 $ 2,668 $ 2,570 Interest Cost 2,814 2,695 5,584 5,390 Expected Return on Plan Assets (3,695 ) (3,265 ) (7,394 ) (6,530 ) Amortizations: Prior Service Cost 53 43 106 86 Actuarial Loss 2,648 1,426 5,304 2,852 Net Periodic Benefit Cost 3,045 2,184 6,268 4,368 Capitalized Benefit Cost (1,194 ) (854 ) (2,433 ) (1,708 ) Deferred Benefit Cost (325 ) — (325 ) — Total Net Periodic Benefit Expense $ 1,526 $ 1,330 $ 3,510 $ 2,660 Other Postretirement Benefits Three Months Ended Six Months Ended 2015 2014 2015 2014 Service Cost $ 231 $ 250 $ 558 $ 500 Interest Cost 715 740 1,487 1,480 Expected Return on Plan Assets (749 ) (687 ) (1,497 ) (1,374 ) Amortizations: Prior Service Cost 152 38 304 76 Actuarial Loss 287 243 671 486 Net Periodic Benefit Cost 636 584 1,523 1,168 Capitalized Benefit Cost (271 ) (209 ) (528 ) (418 ) Deferred Benefit Cost (79 ) — (79 ) — Total Net Periodic Benefit Expense $ 286 $ 375 $ 916 $ 750 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 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	6 Months Ended
	Jun. 30, 2015
Line of Credit Facility [Abstract]
LINES OF CREDIT	LINES OF CREDIT: Credit facilities and available liquidity as of June 30, 2015 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 127,600 $ 72,400 May 2018 Uncommitted Bank Lines 10,000 — 10,000 Various Total SJG 210,000 127,600 82,400 SJI: Revolving Credit Facility 400,000 251,500 148,500 February 2018 (A) Total SJI 400,000 251,500 148,500 Total $ 610,000 $ 379,100 $ 230,900 (A) Includes letters of credit outstanding in the amount of $13.1 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 0.96% and 1.16% at June 30, 2015 and 2014 , respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2015 and 2014 were $274.3 million and $320.2 million , respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2015 and 2014 were $368.1 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 June 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	6 Months Ended
	Jun. 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 June 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 June 30, 2015 , 50% of the currently outstanding debt is $8.4 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 June 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 June 30, 2015 , SJI had issued $5.9 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas. COLLECTIVE BARGAINING AGREEMENTS — Unionized personnel represent approximately 45.0% of our workforce at June 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 June 30, 2015 , SJI provided $13.1 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. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project. PENDING LITIGATION — The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.0 million and $ 2.9 million related to all claims in the aggregate as of June 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	6 Months Ended
	Jun. 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 June 30, 2015 , the Company had outstanding derivative contracts intended to limit the exposure to market risk on 53.1 MMdts (1 MMdts = one million decatherms) of expected future purchases of natural gas, 40.8 MMdts of expected future sales of natural gas, 3.1 MMmwh (1 MMmwh = one million megawatt hours) of expected future purchases of electricity and 3.1 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 274.7 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 June 30, 2015 and December 31, 2014 , are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP June 30, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Energy related commodity contracts: Derivatives – Energy Related – Current $ 73,879 $ 92,914 $ 85,368 $ 109,744 Derivatives – Energy Related – Non-Current 19,204 21,889 13,905 19,926 Interest rate contracts: Derivatives - Other — 9,779 — 10,732 Total derivatives not designated as hedging instruments under GAAP 93,083 124,582 99,273 140,402 Total Derivatives $ 93,083 $ 124,582 $ 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 June 30, 2015 and December 31, 2014 , information related to these offsetting arrangements were as follows (in thousands): As of June 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 $ 93,083 $ — $ 93,083 $ (33,277 ) (A) $ — $ 59,806 Derivatives - Energy Related Liabilities $ (114,803 ) $ — $ (114,803 ) $ 33,277 (B) $ 36,993 $ (44,533 ) Derivatives - Other $ (9,779 ) $ — $ (9,779 ) $ — $ — $ (9,779 ) 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 June 30, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at June 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 six months ended June 30, 2015 and 2014 are as follows (in thousands): Three Months Ended Six 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) $ (187 ) $ (112 ) $ (210 ) $ (224 ) Gains (losses) recognized in income on ineffective portion (a) $ — $ — $ — $ — (a) Included in Interest Charges Three Months Ended Six Months Ended Derivatives Not Designated as Hedging Instruments under GAAP 2015 2014 2015 2014 Gains (losses) on energy related commodity contracts (a) $ 14,685 $ (195 ) $ 7,978 $ (28,796 ) Gains (losses) on interest rate contracts (b) 541 (91 ) 243 (305 ) Total $ 15,226 $ (286 ) $ 8,221 $ (29,101 ) (a) Included in Operating Revenues - Non Utility (b) Included in Interest Charges Net realized loss of $2.1 million and net realized gain of $1.2 million associated with SJG's energy-related financial commodity contracts for the three months ended June 30, 2015 and 2014 , respectively, and a loss of $4.8 million and a gain of $3.6 million for the six months ended June 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 June 30, 2015 , is $40.0 million . If the credit risk-related contingent features underlying these agreements were triggered on June 30, 2015 , the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $35.3 million after offsetting asset positions with the same counterparties under master netting arrangements.

FAIR VALUE OF FINANCIAL ASSETS

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES	6 Months Ended
	Jun. 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 June 30, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 15,121 $ 6,024 $ 9,097 $ — Derivatives – Energy Related Assets (B) 93,083 5,887 39,131 48,065 $ 108,204 $ 11,911 $ 48,228 $ 48,065 Liabilities Derivatives – Energy Related Liabilities (B) $ 114,803 $ 24,684 $ 39,510 $ 50,609 Derivatives – Other (C) 9,779 — 9,779 — $ 124,582 $ 24,684 $ 49,289 $ 50,609 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 June 30, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $28,216 $32,591 Discounted Cash Flow Forward price (per dt) $(1.94) - $11.27 [$2.20] (A) Forward Contract - Electric $19,849 $18,018 Discounted Cash Flow Fixed electric load profile (on-peak) 8.47% - 100.00% [56.92%] (B) Fixed electric load profile (off-peak) 0.00% - 91.53% [43.08%] (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 six months ended June 30, 2015 and 2014 , using significant unobservable inputs (Level 3), are as follows (in thousands): Three Months Ended Six Months Ended June 30, 2015 Balance at beginning of period $ (17,311 ) $ (5,608 ) Other changes in fair value from continuing and new contracts, net 14,376 (2,062 ) Transfers in/(out) of Level 3 (A) 2,054 2,054 Settlements (1,663 ) 3,072 Balance at end of period $ (2,544 ) $ (2,544 ) Three Months Ended Six Months Ended June 30, 2014 Balance at beginning of period $ (4,971 ) $ 8,095 Other changes in fair value from continuing and new contracts, net (2,252 ) (14,376 ) Settlements 2,454 1,512 Balance at end of period $ (4,769 ) $ (4,769 ) (A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the three and six months ended June 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 gains included in earnings for the three months ended June 30, 2015 that are attributable to the change in unrealized gains relating to those assets and liabilities included in Level 3 still held as of June 30, 2015 , are $14.4 million . Total gains/losses included in earnings for the six months ended June 30, 2015 that are attributable to the change in unrealized gains/losses relating to those assets and liabilities included in Level 3 still held as of June 30, 2015 , are not significant. These gains/losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

LONG-TERM DEBT

LONG-TERM DEBT	6 Months Ended
	Jun. 30, 2015
Long-term Debt, Unclassified [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT: The Company did not issue any long-term debt during the six months ended June 30, 2015 . In June 2015, the Company redeemed at maturity $64.0 million aggregate principal amount of 2.39% Senior Notes. No other debt was redeemed during the six months ended June 30, 2015.

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE LOSS	6 Months Ended
	Jun. 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 six months ended June 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 April 1, 2015 (a) $ (27,663 ) $ (2,442 ) $ 13 $ (165 ) $ (30,257 ) Other comprehensive loss before reclassifications — — (43 ) — (43 ) Amounts reclassified from AOCL (b) — 111 (21 ) 59 149 Net current period other comprehensive income (loss) — 111 (64 ) 59 106 Balance at June 30, 2015 (a) $ (27,663 ) $ (2,331 ) $ (51 ) $ (106 ) $ (30,151 ) 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 — — 49 — 49 Amounts reclassified from AOCL (b) — 119 (25 ) (36 ) 58 Net current period other comprehensive income (loss) — 119 24 (36 ) 107 Balance at June 30, 2015 (a) $ (27,663 ) $ (2,331 ) $ (51 ) $ (106 ) $ (30,151 ) (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 six months ended June 30, 2015 : Amounts Reclassified from AOCL (in thousands) Affected Line Item in the Condensed Consolidated Statements of Income Three Months Ended Six Months Ended Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 187 $ 210 Interest Charges Income Taxes (76 ) (91 ) Income Taxes (a) $ 111 $ 119 Unrealized Loss on Available-for-Sale Securities $ (35 ) $ (42 ) Other Income Income Taxes 14 17 Income Taxes (a) $ (21 ) $ (25 ) Loss of Affiliated Companies $ 98 $ (60 ) Equity in Loss of Affiliated Companies Income Taxes (39 ) 24 Income Taxes (a) $ 59 $ (36 ) Losses from reclassifications for the period net of tax $ 149 $ 58 (a) For 2015, determined using a combined average statutory tax rate of 40% .

SUMMARY OF SIGNIFICANT ACCOUN22

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 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. 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	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.
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)	6 Months Ended
	Jun. 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 June 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 45,593 $ 22.19 21.1 % 0.40 % 2013 - EPS 45,593 $ 25.59 N/A N/A 2014 - TSR 51,323 $ 21.31 20.0 % 0.80 % 2014 - EPS 51,323 $ 27.22 N/A N/A 2015 - TSR 34,696 $ 26.31 16.0 % 1.10 % 2015 - EPS, ROE, Time 89,232 $ 29.47 N/A N/A Directors - 2015 25,398 $ 29.34 N/A N/A
Summary of the total stock-based compensation cost for the period	The following table summarizes the total stock-based compensation cost for the three and six months ended June 30, 2015 and 2014 (in thousands): Three Months Ended Six Months Ended 2015 2014 2015 2014 Officers & Key Employees $ 511 $ 586 $ 1,310 $ 1,167 Directors 186 158 372 316 Total Cost 697 744 1,682 1,483 Capitalized (87 ) (70 ) (178 ) (140 ) Net Expense $ 610 $ 674 $ 1,504 $ 1,343
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 six months ended June 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 159,416 25,398 $ 28.69 Cancelled/Forfeited (65,532 ) — $ 26.56 Vested — (23,220 ) $ 27.26 Nonvested Shares Outstanding, June 30, 2015 317,760 25,398 $ 26.10

DISCONTINUED OPERATIONS AND A24

DISCONTINUED OPERATIONS AND AFFILIATIONS (Tables)	6 Months Ended
	Jun. 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 six months ended June 30 , 2015 and 2014, were (in thousands, except per share amounts): Three Months Ended Six Months Ended 2015 2014 2015 2014 Loss Before Income Taxes: Sand Mining $ (17 ) $ (103 ) $ (364 ) $ (483 ) Fuel Oil (97 ) (20 ) (163 ) (122 ) Income Tax Benefits 40 43 177 212 Loss from Discontinued Operations — Net $ (74 ) $ (80 ) $ (350 ) $ (393 ) Earnings (Loss) Per Common Share from Discontinued Operations — Net: Basic and Diluted $ — $ — $ — $ —

COMMON STOCK (Tables)

COMMON STOCK (Tables)	6 Months Ended
	Jun. 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 116,884 Stock-Based Compensation Plan 26,338 Ending Balance, June 30 68,478,082

SEGMENTS OF BUSINESS (Tables)

SEGMENTS OF BUSINESS (Tables)	6 Months Ended
	Jun. 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 Six Months Ended 2015 2014 2015 2014 Operating Revenues: Gas Utility Operations $ 75,812 $ 69,159 $ 343,470 $ 279,704 Energy Group: Wholesale Energy Operations 33,276 (2,936 ) 68,621 32,436 Retail Gas and Other Operations 18,065 24,875 56,143 76,381 Retail Electric Operations 36,186 27,879 65,963 68,272 Subtotal Energy Group 87,527 49,818 190,727 177,089 Energy Services: On-Site Energy Production 15,136 14,397 28,708 25,743 Appliance Service Operations 2,699 2,637 5,056 5,291 Subtotal Energy Services 17,835 17,034 33,764 31,034 Corporate & Services 7,765 6,452 16,851 14,323 Subtotal 188,939 142,463 584,812 502,150 Intersegment Sales (11,229 ) (9,192 ) (24,150 ) (18,678 ) Total Operating Revenues $ 177,710 $ 133,271 $ 560,662 $ 483,472 Three Months Ended Six Months Ended 2015 2014 2015 2014 Operating Income (Loss): Gas Utility Operations $ 11,961 $ 9,005 $ 85,150 $ 72,445 Energy Group: Wholesale Energy Operations 15,158 (8,468 ) 15,488 (10,123 ) Retail Gas and Other Operations 153 (191 ) 3,240 1,777 Retail Electric Operations 174 (840 ) (8 ) (894 ) Subtotal Energy Group 15,485 (9,499 ) 18,720 (9,240 ) Energy Services: On-Site Energy Production 2,177 3,636 1,695 2,376 Appliance Service Operations 247 357 195 262 Subtotal Energy Services 2,424 3,993 1,890 2,638 Corporate and Services 470 256 951 422 Total Operating Income $ 30,340 $ 3,755 $ 106,711 $ 66,265 Depreciation and Amortization: Gas Utility Operations $ 14,239 $ 12,757 $ 28,406 $ 25,433 Energy Group: Wholesale Energy Operations 15 46 47 86 Retail Gas and Other Operations 20 20 40 42 Subtotal Energy Group 35 66 87 128 Energy Services: On-Site Energy Production 7,457 6,165 14,508 11,940 Appliance Service Operations 73 67 147 134 Subtotal Energy Services 7,530 6,232 14,655 12,074 Corporate and Services 458 235 700 454 Total Depreciation and Amortization $ 22,262 $ 19,290 $ 43,848 $ 38,089 Interest Charges: Gas Utility Operations $ 5,113 $ 4,292 $ 10,303 $ 8,634 Energy Group: Wholesale Energy Operations (112 ) (5 ) 130 116 Retail Gas and Other Operations 47 68 120 194 Subtotal Energy Group (65 ) 63 250 310 Energy Services: On-Site Energy Production 1,661 2,147 3,976 4,275 Corporate and Services 2,939 1,790 5,927 3,640 Subtotal 9,648 8,292 20,456 16,859 Intersegment Borrowings (2,174 ) (1,446 ) (4,381 ) (2,929 ) Total Interest Charges $ 7,474 $ 6,846 $ 16,075 $ 13,930 Three Months Ended Six Months Ended 2015 2014 2015 2014 Income Taxes: Gas Utility Operations $ 3,292 $ 2,379 29,464 24,906 Energy Group: Wholesale Energy Operations 5,986 (2,628 ) 6,853 (3,181 ) Retail Gas and Other Operations 92 80 1,668 1,016 Retail Electric Operations 71 (343 ) (3 ) (365 ) Subtotal Energy Group 6,149 (2,891 ) 8,518 (2,530 ) Energy Services: On-Site Energy Production (12,861 ) (9,404 ) (24,908 ) (20,429 ) Appliance Service Operations 105 211 97 188 Subtotal Energy Services (12,756 ) (9,193 ) (24,811 ) (20,241 ) Corporate and Services 36 195 163 224 Total Income Taxes $ (3,279 ) $ (9,510 ) $ 13,334 $ 2,359 Property Additions: Gas Utility Operations $ 62,175 $ 59,067 $ 105,501 $ 91,598 Energy Group: Wholesale Energy Operations 375 8 379 10 Retail Gas and Other Operations 392 229 1,121 397 Subtotal Energy Group 767 237 1,500 407 Energy Services: On-Site Energy Production 26,040 16,426 30,421 25,575 Appliance Service Operations 212 6 328 6 Subtotal Energy Services 26,252 16,432 30,749 25,581 Corporate and Services 537 803 1,601 1,581 Total Property Additions $ 89,731 $ 76,539 $ 139,351 $ 119,167 June 30, 2015 December 31, 2014 Identifiable Assets: Gas Utility Operations $ 2,266,233 $ 2,185,672 Energy Group: Wholesale Energy Operations 269,922 366,119 Retail Gas and Other Operations 35,801 53,073 Retail Electric Operations 47,730 23,682 Subtotal Energy Group 353,453 442,874 Energy Services: On-Site Energy Production 685,765 675,937 Appliance Service Operations 3,425 3,105 Subtotal Energy Services 689,190 679,042 Discontinued Operations 1,600 1,758 Corporate and Services 571,333 527,691 Intersegment Assets (502,863 ) (487,612 ) Total Identifiable Assets $ 3,378,946 $ 3,349,425

REGULATORY ASSETS & REGULATOR27

REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)	6 Months Ended
	Jun. 30, 2015
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Regulatory Assets	Regulatory Assets consisted of the following items (in thousands): June 30, 2015 December 31, 2014 Environmental Remediation Costs: Expended - Net $ 29,145 $ 29,540 Liability for Future Expenditures 125,769 124,308 Deferred Asset Retirement Obligation Costs 31,799 31,584 Deferred Pension and Other Postretirement Benefit Costs 99,040 99,040 Deferred Gas Costs - Net 20,194 32,202 Societal Benefit Costs Receivable — 385 Deferred Interest Rate Contracts 6,615 7,325 Energy Efficiency Tracker 852 11,247 Pipeline Supplier Service Charges 4,608 5,441 Pipeline Integrity Cost 3,851 3,431 AFUDC - Equity Related Deferrals 11,330 10,781 Other Regulatory Assets 1,979 1,876 Total Regulatory Assets $ 335,182 $ 357,160
Schedule of Regulatory Liabilities	Regulatory Liabilities consisted of the following items (in thousands): June 30, 2015 December 31, 2014 Excess Plant Removal Costs $ 34,701 $ 35,940 Conservation Incentive Program Payable 17,255 4,700 Societal Benefit Costs 12,699 — Other Regulatory Liabilities — 1,259 Total Regulatory Liabilities $ 64,655 $ 41,899

PENSION AND OTHER POSTRETIREM28

PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)	6 Months Ended
	Jun. 30, 2015
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
Schedule of defined benefit plans disclosures	For the three and six months ended June 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 Six Months Ended 2015 2014 2015 2014 Service Cost $ 1,225 $ 1,285 $ 2,668 $ 2,570 Interest Cost 2,814 2,695 5,584 5,390 Expected Return on Plan Assets (3,695 ) (3,265 ) (7,394 ) (6,530 ) Amortizations: Prior Service Cost 53 43 106 86 Actuarial Loss 2,648 1,426 5,304 2,852 Net Periodic Benefit Cost 3,045 2,184 6,268 4,368 Capitalized Benefit Cost (1,194 ) (854 ) (2,433 ) (1,708 ) Deferred Benefit Cost (325 ) — (325 ) — Total Net Periodic Benefit Expense $ 1,526 $ 1,330 $ 3,510 $ 2,660 Other Postretirement Benefits Three Months Ended Six Months Ended 2015 2014 2015 2014 Service Cost $ 231 $ 250 $ 558 $ 500 Interest Cost 715 740 1,487 1,480 Expected Return on Plan Assets (749 ) (687 ) (1,497 ) (1,374 ) Amortizations: Prior Service Cost 152 38 304 76 Actuarial Loss 287 243 671 486 Net Periodic Benefit Cost 636 584 1,523 1,168 Capitalized Benefit Cost (271 ) (209 ) (528 ) (418 ) Deferred Benefit Cost (79 ) — (79 ) — Total Net Periodic Benefit Expense $ 286 $ 375 $ 916 $ 750

LINES OF CREDIT (Tables)

LINES OF CREDIT (Tables)	6 Months Ended
	Jun. 30, 2015
Line of Credit Facility [Abstract]
Schedule of lines of credit	Credit facilities and available liquidity as of June 30, 2015 were as follows (in thousands): Company Total Facility Usage Available Liquidity Expiration Date SJG: Commercial Paper Program/Revolving Credit Facility $ 200,000 $ 127,600 $ 72,400 May 2018 Uncommitted Bank Lines 10,000 — 10,000 Various Total SJG 210,000 127,600 82,400 SJI: Revolving Credit Facility 400,000 251,500 148,500 February 2018 (A) Total SJI 400,000 251,500 148,500 Total $ 610,000 $ 379,100 $ 230,900 (A) Includes letters of credit outstanding in the amount of $13.1 million .

DERIVATIVE INSTRUMENTS (Tables)

DERIVATIVE INSTRUMENTS (Tables)	6 Months Ended
	Jun. 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 June 30, 2015 and December 31, 2014 , are as follows (in thousands): Derivatives not designated as hedging instruments under GAAP June 30, 2015 December 31, 2014 Assets Liabilities Assets Liabilities Energy related commodity contracts: Derivatives – Energy Related – Current $ 73,879 $ 92,914 $ 85,368 $ 109,744 Derivatives – Energy Related – Non-Current 19,204 21,889 13,905 19,926 Interest rate contracts: Derivatives - Other — 9,779 — 10,732 Total derivatives not designated as hedging instruments under GAAP 93,083 124,582 99,273 140,402 Total Derivatives $ 93,083 $ 124,582 $ 99,273 $ 140,402
Offsetting assets and liabilities	As of June 30, 2015 and December 31, 2014 , information related to these offsetting arrangements were as follows (in thousands): As of June 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 $ 93,083 $ — $ 93,083 $ (33,277 ) (A) $ — $ 59,806 Derivatives - Energy Related Liabilities $ (114,803 ) $ — $ (114,803 ) $ 33,277 (B) $ 36,993 $ (44,533 ) Derivatives - Other $ (9,779 ) $ — $ (9,779 ) $ — $ — $ (9,779 ) 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 June 30, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets. (B) The balances at June 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 six months ended June 30, 2015 and 2014 are as follows (in thousands): Three Months Ended Six 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) $ (187 ) $ (112 ) $ (210 ) $ (224 ) Gains (losses) recognized in income on ineffective portion (a) $ — $ — $ — $ — (a) Included in Interest Charges Three Months Ended Six Months Ended Derivatives Not Designated as Hedging Instruments under GAAP 2015 2014 2015 2014 Gains (losses) on energy related commodity contracts (a) $ 14,685 $ (195 ) $ 7,978 $ (28,796 ) Gains (losses) on interest rate contracts (b) 541 (91 ) 243 (305 ) Total $ 15,226 $ (286 ) $ 8,221 $ (29,101 ) (a) Included in Operating Revenues - Non Utility (b) Included in Interest Charges

FAIR VALUE OF FINANCIAL ASSET31

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)	6 Months Ended
	Jun. 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 June 30, 2015 Total Level 1 Level 2 Level 3 Assets Available-for-Sale Securities (A) $ 15,121 $ 6,024 $ 9,097 $ — Derivatives – Energy Related Assets (B) 93,083 5,887 39,131 48,065 $ 108,204 $ 11,911 $ 48,228 $ 48,065 Liabilities Derivatives – Energy Related Liabilities (B) $ 114,803 $ 24,684 $ 39,510 $ 50,609 Derivatives – Other (C) 9,779 — 9,779 — $ 124,582 $ 24,684 $ 49,289 $ 50,609 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 June 30, 2015 Valuation Technique Significant Unobservable Input Range [Weighted Average] Assets Liabilities Forward Contract - Natural Gas $28,216 $32,591 Discounted Cash Flow Forward price (per dt) $(1.94) - $11.27 [$2.20] (A) Forward Contract - Electric $19,849 $18,018 Discounted Cash Flow Fixed electric load profile (on-peak) 8.47% - 100.00% [56.92%] (B) Fixed electric load profile (off-peak) 0.00% - 91.53% [43.08%] (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 six months ended June 30, 2015 and 2014 , using significant unobservable inputs (Level 3), are as follows (in thousands): Three Months Ended Six Months Ended June 30, 2015 Balance at beginning of period $ (17,311 ) $ (5,608 ) Other changes in fair value from continuing and new contracts, net 14,376 (2,062 ) Transfers in/(out) of Level 3 (A) 2,054 2,054 Settlements (1,663 ) 3,072 Balance at end of period $ (2,544 ) $ (2,544 ) Three Months Ended Six Months Ended June 30, 2014 Balance at beginning of period $ (4,971 ) $ 8,095 Other changes in fair value from continuing and new contracts, net (2,252 ) (14,376 ) Settlements 2,454 1,512 Balance at end of period $ (4,769 ) $ (4,769 )

ACCUMULATED OTHER COMPREHENSI32

ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)	6 Months Ended
	Jun. 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 six months ended June 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 April 1, 2015 (a) $ (27,663 ) $ (2,442 ) $ 13 $ (165 ) $ (30,257 ) Other comprehensive loss before reclassifications — — (43 ) — (43 ) Amounts reclassified from AOCL (b) — 111 (21 ) 59 149 Net current period other comprehensive income (loss) — 111 (64 ) 59 106 Balance at June 30, 2015 (a) $ (27,663 ) $ (2,331 ) $ (51 ) $ (106 ) $ (30,151 ) 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 — — 49 — 49 Amounts reclassified from AOCL (b) — 119 (25 ) (36 ) 58 Net current period other comprehensive income (loss) — 119 24 (36 ) 107 Balance at June 30, 2015 (a) $ (27,663 ) $ (2,331 ) $ (51 ) $ (106 ) $ (30,151 ) (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 six months ended June 30, 2015 : Amounts Reclassified from AOCL (in thousands) Affected Line Item in the Condensed Consolidated Statements of Income Three Months Ended Six Months Ended Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges $ 187 $ 210 Interest Charges Income Taxes (76 ) (91 ) Income Taxes (a) $ 111 $ 119 Unrealized Loss on Available-for-Sale Securities $ (35 ) $ (42 ) Other Income Income Taxes 14 17 Income Taxes (a) $ (21 ) $ (25 ) Loss of Affiliated Companies $ 98 $ (60 ) Equity in Loss of Affiliated Companies Income Taxes (39 ) 24 Income Taxes (a) $ 59 $ (36 ) Losses from reclassifications for the period net of tax $ 149 $ 58 (a) For 2015, determined using a combined average statutory tax rate of 40% .

SUMMARY OF SIGNIFICANT ACCOUN33

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)	May. 08, 2015	Feb. 26, 2015shares	Jun. 30, 2015USD ($)shares	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)shares	Jun. 30, 2014USD ($)	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	$ 800,000	$ 600,000
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			229,536		229,536			263,578

STOCK-BASED COMPENSATION PLAN34

STOCK-BASED COMPENSATION PLAN (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	Jan. 31, 2015	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of options granted				0	0
Fair value per share (in dollars per share)	$ 24.40	$ 26.10		$ 24.40		$ 24.40
Expected volatility, measurement period				3 years
Service period of shares (in years)				3 years
Cost		$ 697	$ 744	$ 1,682	$ 1,483
Capitalized		(87)	(70)	(178)	(140)
Net Expense		610	674	$ 1,504	$ 1,343
Unrecognized compensation cost of awards granted under the plan		$ 4,600
Weighted average period over which unrecognized compensation cost is to be recognized (in years)				2 years
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)				28.69
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				159,416	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	317,760		223,876		223,876
Cost		$ 511	586	$ 1,310	$ 1,167
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)	223,876			223,876
Granted (in shares)				159,416	136,906
Cancelled/Forfeited (in shares)				(65,532)
Vested (in shares)				0
Nonvested shares outstanding, ending balance (in shares)		317,760		317,760		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)		45,593		45,593
Fair value per share (in dollars per share)		$ 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)		45,593		45,593
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)		45,593		45,593
Fair value per share (in dollars per share)		$ 25.59		$ 25.59
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		45,593		45,593
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)		51,323		51,323
Fair value per share (in dollars per share)		$ 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)		51,323		51,323
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)		51,323		51,323
Fair value per share (in dollars per share)		$ 27.22		$ 27.22
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		51,323		51,323
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)		34,696		34,696
Fair value per share (in dollars per share)		$ 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)		34,696		34,696
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)		89,232		89,232
Fair value per share (in dollars per share)		$ 29.47		$ 29.47
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		89,232		89,232
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				25,398	23,220
Vesting period of shares (in years)				12 months
Shares Vested, Directors		100.00%
Shares outstanding (in shares)	23,220	25,398		23,220		23,220
Cost		$ 186	$ 158	$ 372	$ 316
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)	23,220			23,220
Granted (in shares)				25,398	23,220
Cancelled/Forfeited (in shares)				0
Vested (in shares)				(23,220)
Nonvested shares outstanding, ending balance (in shares)		25,398		25,398		23,220
Additional disclosures [Abstract]
Fair value of shares issued				$ 700	$ 600
Director | 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)		25,398		25,398
Fair value per share (in dollars per share)		$ 29.34		$ 29.34
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)		25,398		25,398
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)		$ 29.34		$ 29.34
Minimum | Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted				0.00%
Maximum | Officers and Key Employees
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted				200.00%
Stock Appreciation Rights (SARs)
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted				0	0
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Granted (in shares)				0	0
Restricted Stock
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	47,824
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)	47,824

DISCONTINUED OPERATIONS AND A35

DISCONTINUED OPERATIONS AND AFFILIATIONS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Loss Before Income Taxes:
Income Tax Benefits	$ 40	$ 43	$ 177	$ 212
Loss from Discontinued Operations — Net	$ (74)	$ (80)	$ (350)	$ (393)
Earnings (Loss) Per Common Share from
Basic and Diluted (in dollars per share)	$ 0	$ 0	$ 0	$ 0
Sand Mining
Loss Before Income Taxes:
Loss Before Income Taxes	$ (17)	$ (103)	$ (364)	$ (483)
Fuel Oil
Loss Before Income Taxes:
Loss Before Income Taxes	$ (97)	$ (20)	$ (163)	$ (122)

DISCONTINUED OPERATIONS AND A36

DISCONTINUED OPERATIONS AND AFFILIATIONS 2 (Details) $ in Millions	6 Months Ended
	Jun. 30, 2015USD ($)mi	Jun. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Affiliations [Abstract]
Investments in unconsolidated affiliates	$ 1.3	$ 3.7
Notes Receivable - affiliate	48.4		$ 51.5
Due from Affiliate, Noncurrent, Secured By Property, Plant, And Equipment	$ 39.2
Interest accrual on secured notes receivable	7.50%
Due from Affiliate, Noncurrent, Unsecured	$ 9.2
Net asset - included in investment in affiliates and other noncurrent liabilities	51.1
Combined equity contributions and the notes receivable - affiliate	$ 100.3
Energenic US LLC
Affiliations [Abstract]
Equity interest	50.00%
Potato Creek, LLC (Potato Creek)
Affiliations [Abstract]
Equity interest	30.00%
PennEast Pipeline Company, LLC (PennEast)
Affiliations [Abstract]
Equity interest	20.00%
Length of Pipeline (in miles) | mi	100

COMMON STOCK (Details)

COMMON STOCK (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Common Stock [Roll Forward]
Beginning balance (in shares)			68,334,860
New Issues During the Period:
Dividend Reinvestment Plan (in shares)			116,884
Stock-Based Compensation Plan (in shares)			26,338
Ending balance (in shares)	68,478,082		68,478,082
Par value of common stock (in dollars per share)	$ 1.25		$ 1.25
Net excess over par value recorded in premium on common stock			$ 4,800
Incremental shares included in diluted EPS calculation (in shares)	186,147	148,664	203,455	151,556
Proceeds from sale of common stock			$ 3,596	$ 17,119

FINANCIAL INSTRUMENTS (Details)

FINANCIAL INSTRUMENTS (Details) $ in Thousands	1 Months Ended	3 Months Ended	12 Months Ended
	Jun. 30, 2015USD ($)term	Jun. 30, 2015USD ($)term	Dec. 31, 2011	Dec. 31, 2014USD ($)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted investments held In escrow	$ 2,600	$ 2,600		$ 1,700
Margin accounts with selected counterparties to support risk management activities	51,100	51,100		63,700
Investment in Affiliates	51,970	51,970		68,351
Notes Receivable - Affiliate	36,300	36,300		36,799
South Jersey Gas Company | Financing Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Long-term receivables, net of unamortized discount	14,000	14,000		15,000
Imputed interest on long term receivables	1,100	1,100		$ 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%	50.00%
Contract term (in years)			20 years
Equity Method Investment, Other than Temporary Impairment		$ 7,700
Investment in Affiliates	$ 2,200	2,200
Notes Receivable - Affiliate	$ 13,900	$ 13,900

FINANCIAL INSTRUMENTS 2 (Detail

FINANCIAL INSTRUMENTS 2 (Details) - Jun. 30, 2015 - Derivatives Energy Related Assets - Supplier Concentration Risk - USD ($) $ in Millions	Total
Concentration Risk [Line Items]
Amount of derivatives - energy related assets with single retail counterparty	$ 8
Percentage of derivatives - energy related assets with a single retail counterparty	8.60%

FINANCIAL INSTRUMENTS 3 (Detail

FINANCIAL INSTRUMENTS 3 (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2010
Schedule of Equity Method Investments [Line Items]
Finance obligation to ACB Energy Partners LLC	$ 19,170	$ 19,659
Estimated fair value of long-term debt	986,400	1,058,500
Carrying amount of long-term debt	$ 945,400	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		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Operating Revenues	$ 177,710	$ 133,271	$ 560,662	$ 483,472
Operating Income (Loss)	30,340	3,755	106,711	66,265
Depreciation and Amortization	22,262	19,290	43,848	38,089
Interest Charges	7,474	6,846	16,075	13,930
Income Taxes	(3,279)	(9,510)	13,334	2,359
Property Additions	89,731	76,539	139,351	119,167
Identifiable Assets	3,378,946		3,378,946		$ 3,349,425
Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues	188,939	142,463	584,812	502,150
Interest Charges	9,648	8,292	20,456	16,859
Operating Segments | Gas Utility Operations
Segment Reporting Information [Line Items]
Operating Revenues	75,812	69,159	343,470	279,704
Operating Income (Loss)	11,961	9,005	85,150	72,445
Depreciation and Amortization	14,239	12,757	28,406	25,433
Interest Charges	5,113	4,292	10,303	8,634
Income Taxes	3,292	2,379	29,464	24,906
Property Additions	62,175	59,067	105,501	91,598
Identifiable Assets	2,266,233		2,266,233		2,185,672
Operating Segments | Energy Group
Segment Reporting Information [Line Items]
Operating Revenues	87,527	49,818	190,727	177,089
Operating Income (Loss)	15,485	(9,499)	18,720	(9,240)
Depreciation and Amortization	35	66	87	128
Interest Charges	(65)	63	250	310
Income Taxes	6,149	(2,891)	8,518	(2,530)
Property Additions	767	237	1,500	407
Identifiable Assets	353,453		353,453		442,874
Operating Segments | Energy Group | Wholesale Energy Operations
Segment Reporting Information [Line Items]
Operating Revenues	33,276	(2,936)	68,621	32,436
Operating Income (Loss)	15,158	(8,468)	15,488	(10,123)
Depreciation and Amortization	15	46	47	86
Interest Charges	(112)	(5)	130	116
Income Taxes	5,986	(2,628)	6,853	(3,181)
Property Additions	375	8	379	10
Identifiable Assets	269,922		269,922		366,119
Operating Segments | Energy Group | Retail Gas and Other Operations
Segment Reporting Information [Line Items]
Operating Revenues	18,065	24,875	56,143	76,381
Operating Income (Loss)	153	(191)	3,240	1,777
Depreciation and Amortization	20	20	40	42
Interest Charges	47	68	120	194
Income Taxes	92	80	1,668	1,016
Property Additions	392	229	1,121	397
Identifiable Assets	35,801		35,801		53,073
Operating Segments | Energy Group | Retail Electric Operations
Segment Reporting Information [Line Items]
Operating Revenues	36,186	27,879	65,963	68,272
Operating Income (Loss)	174	(840)	(8)	(894)
Income Taxes	71	(343)	(3)	(365)
Identifiable Assets	47,730		47,730		23,682
Operating Segments | Energy Services
Segment Reporting Information [Line Items]
Operating Revenues	17,835	17,034	33,764	31,034
Operating Income (Loss)	2,424	3,993	1,890	2,638
Depreciation and Amortization	7,530	6,232	14,655	12,074
Income Taxes	(12,756)	(9,193)	(24,811)	(20,241)
Property Additions	26,252	16,432	30,749	25,581
Identifiable Assets	689,190		689,190		679,042
Operating Segments | Energy Services | On-site Energy Production
Segment Reporting Information [Line Items]
Operating Revenues	15,136	14,397	28,708	25,743
Operating Income (Loss)	2,177	3,636	1,695	2,376
Depreciation and Amortization	7,457	6,165	14,508	11,940
Interest Charges	1,661	2,147	3,976	4,275
Income Taxes	(12,861)	(9,404)	(24,908)	(20,429)
Property Additions	26,040	16,426	30,421	25,575
Identifiable Assets	685,765		685,765		675,937
Operating Segments | Energy Services | Appliance Service Operations
Segment Reporting Information [Line Items]
Operating Revenues	2,699	2,637	5,056	5,291
Operating Income (Loss)	247	357	195	262
Depreciation and Amortization	73	67	147	134
Income Taxes	105	211	97	188
Property Additions	212	6	328	6
Identifiable Assets	3,425		3,425		3,105
Operating Segments | Corporate and Services
Segment Reporting Information [Line Items]
Operating Revenues	7,765	6,452	16,851	14,323
Operating Income (Loss)	470	256	951	422
Depreciation and Amortization	458	235	700	454
Interest Charges	2,939	1,790	5,927	3,640
Income Taxes	36	195	163	224
Property Additions	537	803	1,601	1,581
Identifiable Assets	571,333		571,333		527,691
Discontinued Operations
Segment Reporting Information [Line Items]
Identifiable Assets	1,600		1,600		1,758
Intersegment Elimination
Segment Reporting Information [Line Items]
Operating Revenues	(11,229)	(9,192)	(24,150)	(18,678)
Interest Charges	(2,174)	$ (1,446)	(4,381)	$ (2,929)
Identifiable Assets	$ (502,863)		$ (502,863)		$ (487,612)

RATES AND REGULATORY ACTIONS (D

RATES AND REGULATORY ACTIONS (Details) - USD ($) $ in Millions	1 Months Ended
	Apr. 30, 2015	Jun. 30, 2015	May. 31, 2015	Jan. 31, 2015
Energy Efficiency Tracker
Schedule of Capitalization [Line Items]
Amount of regulatory costs approved, statewide				$ 56
Increase (Decrease) in Amount of Regulatory Costs Approved		$ (7.6)
SHARP
Schedule of Capitalization [Line Items]
Approved base rate increase	$ 4.6
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)
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%
Energy Efficiency Tracker, Over Under Recovery
Schedule of Capitalization [Line Items]
Increase (Decrease) in Amount of Regulatory Costs Approved		$ (1.7)

REGULATORY ASSETS & REGULATOR43

REGULATORY ASSETS & REGULATORY LIABILITIES (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 335,182	$ 357,160
Environmental Remediation Costs: Expended - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	29,145	29,540
Environmental Remediation Costs: Liability for Future Expenditures
Regulatory Assets [Line Items]
Total Regulatory Assets	125,769	124,308
Deferred Asset Retirement Obligation Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	31,799	31,584
Deferred Pension and Other Postretirement Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	99,040	99,040
Deferred Gas Costs - Net
Regulatory Assets [Line Items]
Total Regulatory Assets	20,194	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	6,615	7,325
Energy Efficiency Tracker
Regulatory Assets [Line Items]
Total Regulatory Assets	852	11,247
Pipeline Supplier Service Charges
Regulatory Assets [Line Items]
Total Regulatory Assets	4,608	5,441
Pipeline Integrity Cost
Regulatory Assets [Line Items]
Total Regulatory Assets	3,851	3,431
AFUDC - Equity Related Deferrals
Regulatory Assets [Line Items]
Total Regulatory Assets	11,330	10,781
Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 1,979	$ 1,876

REGULATORY ASSETS & REGULATOR44

REGULATORY ASSETS & REGULATORY LIABILITIES 2 (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 64,655	$ 41,899
Excess Plant Removal Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	34,701	35,940
Conservation Incentive Program Payable
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	17,255	4,700
Societal Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	12,699	0
Other Regulatory Liablities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 0	$ 1,259

PENSION AND OTHER POSTRETIREM45

PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($)	1 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	Jan. 31, 2015	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Pension Benefits
Net periodic benefit cost [Abstract]
Service Cost		$ 1,225,000	$ 1,285,000	$ 2,668,000	$ 2,570,000
Interest Cost		2,814,000	2,695,000	5,584,000	5,390,000
Expected Return on Plan Assets		(3,695,000)	(3,265,000)	(7,394,000)	(6,530,000)
Amortizations:
Prior Service Cost		53,000	43,000	106,000	86,000
Actuarial Loss		2,648,000	1,426,000	5,304,000	2,852,000
Net Periodic Benefit Cost		3,045,000	2,184,000	6,268,000	4,368,000
Capitalized Benefit Cost		(1,194,000)	(854,000)	(2,433,000)	(1,708,000)
Deferred Benefit Cost		(325,000)	0	(325,000)	0
Total Net Periodic Benefit Expense		1,526,000	1,330,000	3,510,000	2,660,000
Contributions	$ 15,000,000					$ 0
Other Postretirement Benefits
Net periodic benefit cost [Abstract]
Service Cost		231,000	250,000	558,000	500,000
Interest Cost		715,000	740,000	1,487,000	1,480,000
Expected Return on Plan Assets		(749,000)	(687,000)	(1,497,000)	(1,374,000)
Amortizations:
Prior Service Cost		152,000	38,000	304,000	76,000
Actuarial Loss		287,000	243,000	671,000	486,000
Net Periodic Benefit Cost		636,000	584,000	1,523,000	1,168,000
Capitalized Benefit Cost		(271,000)	(209,000)	(528,000)	(418,000)
Deferred Benefit Cost		(79,000)	0	(79,000)	0
Total Net Periodic Benefit Expense		$ 286,000	$ 375,000	916,000	$ 750,000
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)		6 Months Ended
		Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)
Line of Credit Facility [Line Items]
Total Facility		$ 610,000,000
Usage		379,100,000
Available Liquidity		230,900,000
Letters of credit outstanding		$ 13,100,000
Weighted average borrowing cost		0.96%	1.16%
Average borrowings outstanding during the period		$ 274,300,000	$ 320,200,000
Maximum amounts outstanding during the period		$ 368,100,000	$ 390,700,000
Financial covenant, ratio of indebtedness to consolidated total capitalization		0.65 to 1
Minimum
Line of Credit Facility [Line Items]
Financial covenant, ratio of indebtedness to consolidated total capitalization minimum		0.65
SJG Commercial Paper Program
Line of Credit Facility [Line Items]
Total Facility		$ 200,000,000
Fixed maturities of notes, at maximum number of days (in days)		270 days
South Jersey Gas Company
Line of Credit Facility [Line Items]
Total Facility		$ 210,000,000
Usage		127,600,000
Available Liquidity		82,400,000
South Jersey Gas Company | Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility		200,000,000
Usage		127,600,000
Available Liquidity		72,400,000
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		251,500,000
Available Liquidity		148,500,000
South Jersey Industries Inc | Revolving Credit Facility
Line of Credit Facility [Line Items]
Total Facility	[1]	400,000,000
Usage	[1]	251,500,000
Available Liquidity	[1]	$ 148,500,000
[1]	Includes letters of credit outstanding in the amount of $13.1 million.

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details) $ in Thousands	1 Months Ended	6 Months Ended
	May. 31, 2012	Jun. 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		$ 12,059	$ 14,657
Collective bargaining agreements [Abstract]
Percentage of personnel represented by collective bargaining agreements		45.00%
Number of unions (in unions) | unions		2
Letter of credit provided		$ 610,000
Pending litigation [Abstract]
Estimated litigation liability		3,000	$ 2,900
Environmental remediation costs [Abstract]
Number of sites for environmental cleanup (in number of sites) | sites			12
Standby Letter of Credit
Collective bargaining agreements [Abstract]
Letter of credit provided		13,100
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		8,400
Parental Guarantee
Guarantees [Abstract]
Guaranteed amount		$ 5,900

DERIVATIVE INSTRUMENTS (Details

DERIVATIVE INSTRUMENTS (Details) - Jun. 30, 2015 dts in Millions, MWh in Millions	MWhdts
Basis and Index Related Purchase and Sales Contracts
Derivative [Line Items]
Outstanding derivative contracts notional amount	274.7
Natural Gas (in MMdts) | Derivative Transaction Type, Purchase
Derivative [Line Items]
Outstanding derivative contracts notional amount	53.1
Natural Gas (in MMdts) | Derivative Transaction Type, Sale
Derivative [Line Items]
Outstanding derivative contracts notional amount	40.8
Electricity (in MMmwh) | Derivative Transaction Type, Purchase
Derivative [Line Items]
Outstanding derivative contracts notional amount | MWh	3.1
Electricity (in MMmwh) | Derivative Transaction Type, Sale
Derivative [Line Items]
Outstanding derivative contracts notional amount | MWh	3.1

DERIVATIVE INSTRUMENTS 2 (Detai

DERIVATIVE INSTRUMENTS 2 (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	$ 93,083	$ 99,273
Fair value Derivative Liabilities	124,582	140,402
Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	93,083	99,273
Fair value Derivative Liabilities	124,582	140,402
Commodity Contract | Not Designated as Hedging Instrument | Derivatives-Energy Related-Current
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	73,879	85,368
Fair value Derivative Liabilities	92,914	109,744
Commodity Contract | Not Designated as Hedging Instrument | Derivatives-Energy Related-NonCurrent
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	19,204	13,905
Fair value Derivative Liabilities	21,889	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	$ 9,779	$ 10,732

DERIVATIVE INSTRUMENTS 3 (Detai

DERIVATIVE INSTRUMENTS 3 (Details) - USD ($) $ in Thousands		Jun. 30, 2015	Dec. 31, 2014
Commodity Contract
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities		$ 93,083	$ 99,273
Gross amount offset in the balance sheet		0	0
Net amounts of assets/liabilities in balance sheet		93,083	99,273
Gross amounts not offset in the balance sheet, Financial Instruments	[1]	(33,277)	(39,747)
Gross amounts not offset in the balance sheet, Cash Collateral Posted		0	0
Net amount		59,806	59,526
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities		(114,803)	(129,670)
Gross amount offset in the balance sheet		0	0
Net amounts of assets/liabilities in balance sheet		(114,803)	(129,670)
Gross amounts not offset in the balance sheet, Financial Instruments	[2]	33,277	39,747
Gross amounts not offset in the balance sheet, Cash Collateral Posted		36,993	53,897
Net amount		(44,533)	(36,026)
Interest Rate Contract
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities		(9,779)	(10,732)
Gross amount offset in the balance sheet		0	0
Net amounts of assets/liabilities in balance sheet		(9,779)	(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		$ (9,779)	$ (10,732)
[1]	The balances at June 30, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets.
[2]	The balances at June 30, 2015 and December 31, 2014 were related to derivative assets which can be net settled against derivative liabilities.

DERIVATIVE INSTRUMENTS 4 (Detai

DERIVATIVE INSTRUMENTS 4 (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Interest Rate Contracts:
Losses recognized in AOCL on effective portion		$ 0	$ 0	$ 0	$ 0
Losses reclassified from AOCL into income	[1]	(187)	(112)	(210)	(224)
Gains (losses) recognized in income on ineffective portion	[1]	0	0	0	0
Total		15,226	(286)	8,221	(29,101)
Net realized gains (losses), derivative instruments, energy-related contracts		(2,100)	1,200	(4,800)	3,600
Fair value derivative instruments with credit-risk-related features		40,000		40,000
Additional collateral, aggregate fair value		35,300		35,300
Not Designated as Hedging Instrument
Interest Rate Contracts:
Gain (losses) on energy related commodity contracts	[2]	14,685	(195)	7,978	(28,796)
Gain (losses) on interest rate contracts	[1]	$ 541	$ (91)	$ 243	$ (305)
[1]	Included in Interest Charges
[2]	Included in Operating Revenues - Non Utility

FAIR VALUE OF FINANCIAL ASSET52

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period		$ (17,311)	$ (4,971)	$ (5,608)	$ 8,095
Other changes in fair value from continuing and new contracts, net		14,376	(2,252)	(2,062)	(14,376)
Transfers in/(out) of Level 3	[1]	2,054		2,054
Settlements		(1,663)	2,454	3,072	1,512
Balance at end of period		$ (17,311)	$ (4,971)	$ (5,608)	$ 8,095	$ (2,544)	$ (5,608)	$ (4,769)
Fair Value, Measurements, Recurring
Assets
Available-for-Sale Securities	[2]					15,121	8,922
Derivatives - Energy Related Assets	[3]					93,083	99,273
Total Assets						108,204	108,195
Liabilities
Derivatives - Energy Related Liabilities	[3]					114,803	129,670
Derivatives - Other	[4]					9,779	10,732
Total Liabilities						124,582	140,402
Fair Value, Measurements, Recurring | Level 1
Assets
Available-for-Sale Securities	[2]					6,024	5,952
Derivatives - Energy Related Assets	[3]					5,887	21,675
Total Assets						11,911	27,627
Liabilities
Derivatives - Energy Related Liabilities	[3]					24,684	49,009
Derivatives - Other	[4]					0	0
Total Liabilities						24,684	49,009
Fair Value, Measurements, Recurring | Level 2
Assets
Available-for-Sale Securities	[2]					9,097	2,970
Derivatives - Energy Related Assets	[3]					39,131	43,093
Total Assets						48,228	46,063
Liabilities
Derivatives - Energy Related Liabilities	[3]					39,510	40,548
Derivatives - Other	[4]					9,779	10,732
Total Liabilities						49,289	51,280
Fair Value, Measurements, Recurring | Level 3
Assets
Available-for-Sale Securities	[2]					0	0
Derivatives - Energy Related Assets	[3]					48,065	34,505
Total Assets						48,065	34,505
Liabilities
Derivatives - Energy Related Liabilities	[3]					50,609	40,113
Derivatives - Other	[4]					0	0
Total Liabilities						$ 50,609	$ 40,113
[1]	Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the three and six months ended June 30, 2015, $2.1 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data.
[2]	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.
[3]	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.
[4]	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.

FAIR VALUE OF FINANCIAL ASSET53

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES, LEVEL THREE INPUTS (Details) - Forward Contracts - Fair Value, Inputs, Level 3 $ in Thousands		Jun. 30, 2015USD ($)$ / decatherm	Dec. 31, 2014USD ($)$ / decatherm
Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets		$ 28,216	$ 26,485
Liabilities		32,591	33,882
Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets		19,849	8,020
Liabilities		$ 18,018	$ 6,231
Minimum | Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) | $ / decatherm	[1]	(1.94)	(2.04)
Maximum | Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) | $ / decatherm	[1]	11.27	7.83
Weighted Average | Natural Gas
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt) | $ / decatherm	[1]	2.20	(0.30)
On-Peak | Minimum | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	[2]	8.47%	8.06%
On-Peak | Maximum | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	[2]	100.00%	100.00%
On-Peak | Weighted Average | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	[2]	56.92%	55.97%
Off-Peak | Minimum | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	[2]	0.00%	0.00%
Off-Peak | Maximum | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	[2]	91.53%	91.94%
Off-Peak | Weighted Average | Electricity
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	[2]	43.08%	44.03%
[1]	Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas.
[2]	Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak.

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details) - Jun. 30, 2015 - USD ($) $ in Millions	Total
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.50%
Senior Notes | Series A Notes Due 2015, 2.39%
Debt Instrument [Line Items]
Debt Instrument, Repurchase Face Amount	$ 64
Debt Instrument, Interest Rate, Stated Percentage	2.39%

ACCUMULATED OTHER COMPREHENSI55

ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	[1]	$ (30,257)		$ (30,258)
Other comprehensive income before reclassifications		(43)		49
Amounts reclassified from AOCL	[2]	149		58
Other Comprehensive Income - Net of Tax	[3]	106	$ 138	107	$ 248
Ending balance	[1]	(30,151)		$ (30,151)
Combined statutory tax rate				40.00%	41.00%
Postretirement Liability Adjustment
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	[1]	(27,663)		$ (27,663)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL	[2]	0		0
Other Comprehensive Income - Net of Tax		0		0
Ending balance	[1]	(27,663)		(27,663)
Unrealized Gain (Loss) on Derivatives-Other
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	[1]	(2,442)		(2,450)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL	[2]	111		119
Other Comprehensive Income - Net of Tax		111		119
Ending balance	[1]	(2,331)		(2,331)
Unrealized Gain (Loss) on Available-for-Sale Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	[1]	13		(75)
Other comprehensive income before reclassifications		(43)		49
Amounts reclassified from AOCL	[2]	(21)		(25)
Other Comprehensive Income - Net of Tax		(64)		24
Ending balance	[1]	(51)		(51)
Other Comprehensive Income (Loss) of Affiliated Companies
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	[1]	(165)		(70)
Other comprehensive income before reclassifications		0		0
Amounts reclassified from AOCL	[2]	59		(36)
Other Comprehensive Income - Net of Tax		59		(36)
Ending balance	[1]	$ (106)		$ (106)
[1]	For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.
[2]	See table below.
[3]	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 COMPREHENSI56

ACCUMULATED OTHER COMPREHENSIVE LOSS 2 (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges		$ 7,474	$ 6,846	$ 16,075	$ 13,930
Other Income		(3,040)	(4,185)	(5,281)	(6,553)
Equity in Loss of Affiliated Companies		15,844	903	15,389	(1,383)
Income Taxes		(3,279)	(9,510)	13,334	2,359
(Loss) Income from Continuing Operations		(13,341)	$ (9,701)	(67,194)	$ (57,912)
Reclassification out of Accumulated Other Comprehensive Income
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
(Loss) Income from Continuing Operations		149		58
Reclassification out of Accumulated Other Comprehensive Income | Unrealized Gain (Loss) on Derivatives-Other
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges		187		210
Income Taxes	[1]	(76)		(91)
(Loss) Income from Continuing Operations		111		119
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		(35)		(42)
Income Taxes	[1]	14		17
(Loss) Income from Continuing Operations		(21)		(25)
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		98		(60)
Income Taxes	[1]	(39)		24
(Loss) Income from Continuing Operations		$ 59		$ (36)
[1]	For 2015, determined using a combined average statutory tax rate of 40%.