10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10-Q

(Mark one)

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2013

OR

o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ________________ to __________________

Commission File Number 1-6364

SOUTH JERSEY INDUSTRIES, INC.

(Exact name of registrant as specified in its charter)

New Jersey	22-1901645
(State of incorporation)	(IRS employer identification no.)

1 South Jersey Plaza, Folsom, NJ 08037

(Address of principal executive offices, including zip code)

(609) 561-9000

(Registrant’s telephone number, including area code)

Common Stock
($1.25 par value per share)	New York Stock Exchange
(Title of each class)	(Name of exchange on which registered)

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.   Yes x   No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x   No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.  See the definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer   x	Accelerated filer      o
Non-accelerated filer     o (Do not check if a smaller reporting company)	Smaller reporting company      o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o  No x

As of August 1, 2013 there were 31,984,745 shares of the registrant’s common stock outstanding.

TABLE OF CONTENTS

		PageNo.
PART I	FINANCIAL INFORMATION
Item 1.	Unaudited Condensed Consolidated Financial Statements	1
	Condensed Consolidated Statements of Income	1
	Condensed Consolidated Statements of Comprehensive Income	3
	Condensed Consolidated Statements of Cash Flows	4
	Condensed Consolidated Balance Sheets	5
	Notes to Unaudited Condensed Consolidated Financial Statements	7
	Note  1. Summary of Significant Accounting Policies	7
	Note  2. Stock-Based Compensation Plan	8
	Note  3. Discontinued Operations and Affiliations	10
	Note  4. Common Stock	11
	Note  5. Financial Instruments	11
	Note  6. Segments of Business	13
	Note  7. Rates and Regulatory Actions	16
	Note  8. Regulatory Assets & Regulatory Liabilities	16
	Note  9. Pension and Other Postretirement Benefits	18
	Note 10.Unused Lines of Credit	19
	Note 11. Commitments and Contingencies	20
	Note 12. Derivative Instruments	22
	Note 13. Fair Value of Financial Assets and Financial Liabilities	24
	Note 14. Long-Term Debt	27
	Note 15. Accumulated Other Comprehensive Loss	28
	Note 16. Subsequent Event	29
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	48
Item 4.	Controls and Procedures	50
PART II	OTHER INFORMATION
Item 1.	Legal Proceedings	51
Item 1A.	Risk Factors	51
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	51
Item 6.	Exhibits	51
Signatures		52

Item 1. Unaudited Condensed Consolidated Financial Statements

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

(In Thousands Except for Per Share Data)

	Three Months Ended June 30,
	2013			2012
Operating Revenues:
Utility	$	66,040		$	59,056
Nonutility	56,552			62,857
Total Operating Revenues	122,592			121,913
Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility	25,611			20,286
- Nonutility	62,216			49,233
Operations	27,957			26,416
Maintenance	3,365			3,371
Depreciation	12,372			10,485
Energy and Other Taxes	1,664			1,865
Total Operating Expenses	133,185			111,656
Operating (Loss) Income	(10,593		)	10,257
Other Income and Expense	2,665			3,658
Interest Charges	(3,420		)	(5,195		)
(Loss) Income Before Income Taxes	(11,348		)	8,720
Income Tax Benefit	11,632			1,072
Equity in Earnings of Affiliated Companies	632			1,040
Income from Continuing Operations	916			10,832
Loss from Discontinued Operations - (Net of tax benefit)	(28		)	(498		)
Net Income	$	888		$	10,334
Basic Earnings Per Common Share:
Continuing Operations	$	0.029		$	0.356
Discontinued Operations	(0.001		)	(0.016		)
Basic Earnings Per Common Share	$	0.028		$	0.340
Average Shares of Common Stock Outstanding - Basic	31,949			30,393
Diluted Earnings Per Common Share:
Continuing Operations	$	0.029		$	0.355
Discontinued Operations	(0.001		)	(0.016		)
Diluted Earnings Per Common Share	$	0.028		$	0.339
Average Shares of Common Stock Outstanding - Diluted	32,012			30,472
Dividends Declared per Common Share	$	0.443		$	0.403

The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

1

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

(In Thousands Except for Per Share Data)

	Six Months Ended June 30,
	2013			2012
Operating Revenues:
Utility	$	239,691		$	238,258
Nonutility	138,531			158,487
Total Operating Revenues	378,222			396,745
Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility	102,766			106,551
- Nonutility	137,361			119,836
Operations	60,646			54,198
Maintenance	6,787			6,563
Depreciation	23,779			20,089
Energy and Other Taxes	5,497			5,743
Total Operating Expenses	336,836			312,980
Operating Income	41,386			83,765
Other Income and Expense	6,534			5,531
Interest Charges	(8,128		)	(10,688		)
Income Before Income Taxes	39,792			78,608
Income Tax Benefit (Expense)	3,860			(14,812		)
Equity in Earnings of Affiliated Companies	601			1,247
Income from Continuing Operations	44,253			65,043
Loss from Discontinued Operations - (Net of tax benefit)	(499		)	(634		)
Net Income	$	43,754		$	64,409
Basic Earnings Per Common Share:
Continuing Operations	$	1.389		$	2.145
Discontinued Operations	(0.015		)	(0.021		)
Basic Earnings Per Common Share	$	1.374		$	2.124
Average Shares of Common Stock Outstanding - Basic	31,853			30,321
Diluted Earnings Per Common Share:
Continuing Operations	$	1.387		$	2.140
Discontinued Operations	(0.016		)	(0.021		)
Diluted Earnings Per Common Share	$	1.371		$	2.119
Average Shares of Common Stock Outstanding - Diluted	31,912			30,397
Dividends Declared per Common Share	$	0.886		$	0.806

The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

2

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(In Thousands)

	Three Months Ended June 30,
	2013			2012
Net Income	$	888		$	10,334
Other Comprehensive Income (Loss), Net of Tax:*
Unrealized Loss on Available-for-Sale Securities	(23		)	(136		)
Unrealized Gain (Loss) on Derivatives - Other	66			(415		)
Other Comprehensive Income of Affiliated Companies	22			320
Other Comprehensive Income (Loss) - Net of Tax*	65			(231		)
Comprehensive Income	$	953		$	10,103

	Six Months Ended June 30,
	2013			2012
Net Income	$	43,754		$	64,409
Other Comprehensive Income (Loss), Net of Tax:*
Unrealized (Loss) Gain on Available-for-Sale Securities	(297		)	215
Unrealized Gain (Loss) on Derivatives - Other	132			(225		)
Other Comprehensive Income (Loss) of Affiliated Companies	5,036			(1,962		)
Other Comprehensive Income (Loss) - Net of Tax*	4,871			(1,972		)
Comprehensive Income	$	48,625		$	62,437

* Determined using a combined statutory tax rate of 41%.

The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

3

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(In Thousands)

	Six Months Ended June 30,
	2013			2012
Net Cash Provided by Operating Activities	$	62,509		$	56,213
Cash Flows from Investing Activities:
Capital Expenditures	(88,305		)	(96,891		)
Net (Purchase of) Proceeds from Sale of Restricted Investments in Margin Account	(13,840		)	7,775
Purchase of Restricted Investments with Escrowed Loan Proceeds	(40		)	—
Investment in Long-Term Receivables	(3,256		)	(2,871		)
Proceeds from Long-Term Receivables	3,433			3,781
Purchase of Company Owned Life Insurance	(3,785		)	(3,525		)
Investment in Affiliate	(2,492		)	(28,979		)
Advances on Notes Receivable - Affiliate	(6,157		)	(58,178		)
Repayment of Notes Receivable - Affiliate	94,360			4,681
Other	—			(584		)
Net Cash Used in Investing Activities	(20,082		)	(174,791		)
Cash Flows from Financing Activities:
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(43,200		)	1,900
Proceeds from Issuance of Long-Term Debt	—			150,000
Principal Repayments of Long-Term Debt	—			(35,000		)
Payments for Issuance of Long-Term Debt	(5		)	(583		)
Premium for Early Retirement of Debt	—			(700		)
Dividends on Common Stock	(14,102		)	(12,200		)
Proceeds from Sale of Common Stock	12,502			9,256
Net Cash (Used in) Provided by Financing Activities	(44,805		)	112,673
Net Decrease in Cash and Cash Equivalents	(2,378		)	(5,905		)
Cash and Cash Equivalents at Beginning of Period	4,638			7,538
Cash and Cash Equivalents at End of Period	$	2,260		$	1,633

The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

4

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

(In Thousands)

	June 30, 2013			December 31, 2012
Assets
Property, Plant and Equipment:
Utility Plant, at original cost	$	1,735,375		$	1,658,790
Accumulated Depreciation	(384,762		)	(373,199		)
Nonutility Property and Equipment, at cost	351,091			328,638
Accumulated Depreciation	(43,589		)	(36,208		)
Property, Plant and Equipment - Net	1,658,115			1,578,021
Investments:
Available-for-Sale Securities	7,859			7,538
Restricted	31,783			17,903
Investment in Affiliates	78,388			75,825
Total Investments	118,030			101,266
Current Assets:
Cash and Cash Equivalents	2,260			4,638
Accounts Receivable	246,460			195,293
Unbilled Revenues	14,549			40,938
Provision for Uncollectibles	(6,943		)	(5,924		)
Notes Receivable - Affiliate	5,287			39,495
Natural Gas in Storage, average cost	58,440			55,517
Materials and Supplies, average cost	2,647			2,618
Prepaid Taxes	18,378			26,187
Derivatives - Energy Related Assets	33,826			24,242
Other Prepayments and Current Assets	18,103			11,833
Total Current Assets	393,007			394,837
Regulatory and Other Noncurrent Assets:
Regulatory Assets	326,406			352,656
Derivatives - Energy Related Assets	14,642			12,297
Unamortized Debt Issuance Costs	7,820			8,226
Notes Receivable-Affiliate	65,828			117,188
Contract Receivables	13,782			13,985
Other	56,867			52,964
Total Regulatory and Other Noncurrent Assets	485,345			557,316
Total Assets	$	2,654,497		$	2,631,440

The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

5

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

(In Thousands)

	June 30, 2013			December 31, 2012
Capitalization and Liabilities
Equity:
Common Stock	$	39,954		$	39,567
Premium on Common Stock	359,431			345,807
Treasury Stock (at par)	(169		)	(182		)
Accumulated Other Comprehensive Loss	(26,234		)	(31,105		)
Retained Earnings	397,611			382,127
Total Equity	770,593			736,214
Long-Term Debt	601,400			601,400
Total Capitalization	1,371,993			1,337,614
Current Liabilities:
Notes Payable	295,700			338,900
Current Portion of Long-Term Debt	25,000			25,000
Accounts Payable	192,381			193,331
Customer Deposits and Credit Balances	17,240			17,757
Environmental Remediation Costs	25,691			21,026
Taxes Accrued	2,462			2,156
Derivatives - Energy Related Liabilities	37,979			23,828
Deferred Income Taxes - Net	5,678			10,812
Deferred Contract Revenues	42			—
Dividends Payable	14,165			—
Interest Accrued	7,629			6,635
Pension Benefits	1,236			1,272
Other Current Liabilities	7,136			11,127
Total Current Liabilities	632,339			651,844
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	291,928			289,489
Investment Tax Credits	489			618
Pension and Other Postretirement Benefits	97,283			105,168
Environmental Remediation Costs	88,379			91,072
Asset Retirement Obligations	40,067			39,385
Derivatives - Energy Related Liabilities	25,563			5,403
Derivatives - Other	9,091			13,462
Regulatory Liabilities	60,615			56,517
Finance Obligation	21,150			21,646
Other	15,600			19,222
Total Deferred Credits and Other Noncurrent Liabilities	650,165			641,982
Commitments and Contingencies  (Note 11)
Total Capitalization and Liabilities	$	2,654,497		$	2,631,440

The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

6

Notes to Unaudited Condensed Consolidated Financial Statements

1. 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.

▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects.

▪ 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 Energy Service Plus, LLC (SJESP) services residential and 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, and the installation of small commercial HVAC systems.

▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.

BASIS OF PRESENTATION — The condensed consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which we have a controlling interest. We eliminate 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 2012 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.

Certain reclassifications have been made to the prior period segment disclosures to conform to the current period presentation. In all periods presented, net receivables between the Discontinued Operations segment and the Corporate and Services segment have been reclassified in the Identifiable Assets Segment disclosure in Note 6.

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). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both utility revenue and cost of sales and totaled $0.7 million and $0.9 million for the three months ended June 30, 2013 and 2012, respectively, and $2.9 million and $3.4 million for the six months ended June 30, 2013 and 2012, respectively. The TEFA is subject to a planned phase-out which decreases the assessment in increments of 25% in 2012 and 2013 and is eliminated after December 31, 2013.

IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. The Company recorded a $1.1 million impairment charge during the six months ended June 30, 2012 related to certain shallow wells in the Marcellus region as discussed under “Gas Exploration and Development”.  For the six months ended June 30, 2013, no impairments were identified.

7

GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. No impairment was recorded during the six months ended June 30, 2013. During the six months ended June 30, 2012, the Company recorded $1.1 million of impairment charges within Other Income and Expense on the condensed consolidated statement of income due to a reduction in the expected cash flows to be received from certain shallow wells in the Marcellus region. As of both June 30, 2013 and December 31, 2012, $9.0 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, 2013 and December 31, 2012, SJI held 134,783 and 145,414 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 the non-regulated entities 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 2013 and 2012 had, or is expected to have, a material impact on the condensed consolidated financial statements.

In January 2012, the FASB issued Accounting Standards Update (ASU) 2011-11, Enhanced Disclosure Requirements Concerning Offsetting of Financial Assets and Financial Liabilities. This ASU amends ASC 210-20 to add disclosure requirements in respect of the offsetting of financial assets and financial liabilities. In February 2013, the FASB issued ASU 2013-01 Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which amends and clarifies the scope of the balance sheet offsetting disclosures required through ASU 2011-11. The new guidance is effective for fiscal years beginning on or after January 1, 2013. The adoption of this guidance modified the disclosures around derivative instruments, but did not have an impact on the Company's financial statement results.

In February 2013, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.

2. STOCK-BASED COMPENSATION PLAN:

Under the Amended and Restated 1997 Stock-Based Compensation Plan, no more than 2,000,000 shares in the aggregate may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. The plan will terminate on January 26, 2015, unless terminated earlier by the Board of Directors. No options were granted or outstanding during the six months ended June 30, 2013 and 2012.  No stock appreciation rights have been issued under the plan. During the six months ended June 30, 2013 and 2012, SJI granted 56,464 and 40,955 restricted shares to Officers and other key employees, respectively.  These restricted shares vest over a three-year period and are subject to SJI achieving certain market and earnings-based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 150% of the original share units granted. Grants containing market-based performance targets have been issued in each of the last three years and use SJI's total shareholder return (TSR) relative to a peer group to measure performance. Beginning with 2012, grants containing earnings-based targets have also been issued. These new grants are based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance. During the six months ended June 30, 2013 and 2012, SJI granted 12,285 and 9,904 restricted shares, respectively, to Directors.  Shares issued to Directors in 2011 vest over a three-year service period and contain no performance conditions. Shares issued to Directors in 2012 and 2013 vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest.

8

See Note 2 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012 for the related accounting policy.

The following table summarizes the nonvested restricted stock awards outstanding at June 30, 2013 and the assumptions used to estimate the fair value of the awards:

	Grant Date	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Officers & Key Employees -	Jan. 2011 - TSR	40,069	$	50.940	27.5	%	1.01	%
	Jan. 2012 - TSR	20,090	$	51.230	22.5	%	0.43	%
	Jan. 2012 - EPS	20,090	$	56.930	N/A		N/A
	Jan. 2013 - TSR	27,763	$	44.380	21.1	%	0.40	%
	Jan. 2013 - EPS	27,763	$	51.180	N/A		N/A
Directors -	Jan. 2011	7,332	$	52.940	—		—
	Jan. 2013	12,285	$	51.740	—		—

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, 2013 and 2012 (in thousands):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Officers & Key Employees	$	566		$	524		$	1,139		$	1,048
Directors	191			228			382			354
Total Cost	757			752			1,521			1,402
Capitalized	(63		)	(58		)	(126		)	(115		)
Net Expense	$	694		$	694		$	1,395		$	1,287

As of June 30, 2013, there was $4.0 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the restricted stock plans. That cost is expected to be recognized over a weighted average period of 1.9 years.

The following table summarizes information regarding restricted stock award activity during the six months ended June 30, 2013, excluding accrued dividend equivalents:

	Officers &Other Key Employees		Directors		Weighted Average Fair Value
Nonvested Shares Outstanding, January 1, 2013	81,005		27,688		$	51.292
Granted	56,464		12,285		$	48.488
Cancelled/Forfeited	(1,694	)	—		$	50.302
Vested	—		(20,356	)	$	45.809
Nonvested Shares Outstanding, June 30, 2013	135,775		19,617		$	50.780

9

During the six months ended June 30, 2013 and 2012, SJI awarded 66,077 shares to its Officers and other key employees, which had vested at December 31, 2012, at a market value of $3.3 million, and 33,322 shares, which had vested at December 31, 2011, at a market value of $1.9 million, respectively. Also, during the six months ended June 30, 2013 and 2012, SJI awarded 12,285 and 9,904 shares to its Directors at a market value of $0.6 million for each period. The Company has a policy of issuing new shares to satisfy its obligations under these plans; therefore, there are no cash payment requirements resulting from the normal operation of these plans. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash.  At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods.  These deferred shares are included in Treasury Stock on the condensed consolidated balance sheets.

3. 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, were (in thousands, except per share amounts):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Loss Before Income Taxes:
Sand Mining	$	(20	)	$	(705	)	$	(92	)	$	(901	)
Fuel Oil	(23		)	(61		)	(675		)	(75		)
Income Tax Benefits	15			268			268			342
Loss from Discontinued Operations — Net	$	(28	)	$	(498	)	$	(499	)	$	(634	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic	$	(0.001	)	$	(0.016	)	$	(0.015	)	$	(0.021	)
Diluted	$	(0.001	)	$	(0.016	)	$	(0.016	)	$	(0.021	)

AFFILIATIONS — The following affiliated entities are accounted for under the equity method:

Energenic – US, LLC (Energenic) - Marina and a joint venture partner formed Energenic, in which Marina has a 50% equity interest. Energenic develops and operates on-site, self-contained, energy-related projects.

In April 2012, Energenic acquired The Energy Network, LLC, a holding company for the Hartford Steam Company, TEN Companies and CNE Power I, LLC. In conjunction with this acquisition, Marina provided $35.4 million of advances to Energenic, which was repaid by Energenic during the second quarter of 2013 as permanent financing was obtained.

Potato Creek, LLC (Potato Creek) - SJI and a joint venture partner formed Potato Creek, in which SJI has a 30% equity interest.  Potato Creek owns and manages the oil, gas and mineral rights of certain real estate in Pennsylvania.

LVE Energy Partners, LLC (LVE) - In March 2013, substantially all of the assets of Marina's joint venture, LVE, an entity in which Marina has a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.6 million. See Note 11.

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During the first six months of 2013 and 2012, the Company made investments in, and provided net advances to, unconsolidated affiliates of $7.3 million and $82.5 million, respectively. These amounts do not include the cash proceeds from LVE and the repayment of the advances to Energenic as discussed above. The purpose of these investments and advances was to cover certain project related costs of affiliates.   As of June 30, 2013 and December 31, 2012, the outstanding balance on these Notes Receivable – Affiliate was $71.1 million and $156.7 million, respectively. Approximately $64.1 million of these notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025. The remaining $7.0 million of these notes are unsecured, and are either non-interest bearing or accrue interest at variable rates and are to be repaid when the affiliate secures permanent financing.

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, 2013, the Company had a net asset of approximately $78.0 million included in Investment in Affiliates and Other Noncurrent Liabilities on the condensed consolidated balance sheets related to equity method investees, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of June 30, 2013 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $150.6 million.

4. COMMON STOCK:

The following shares were issued and outstanding at June 30:

	2013
Beginning Balance, January 1	31,653,262
New Issues During the Period:
Dividend Reinvestment Plan	231,485
Stock-Based Compensation Plan	78,363
Ending Balance, June 30	31,963,110

The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $13.6 million was recorded in Premium on Common Stock.

EARNINGS PER COMMON SHARE (EPS) — Basic EPS is based on the weighted-average number of common shares outstanding.  The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 63,174 and 79,355 for the three months ended June 30, 2013 and 2012, respectively, and 58,374 and 76,313 for the six months ended June 30, 2013 and 2012, 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 $12.5 million and $9.3 million of equity capital through the DRP during the six months ended June 30, 2013 and 2012, respectively.

5. 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, 2013 and December 31, 2012, the escrowed proceeds, including interest earned, totaled $1.4 million and $1.3 million, respectively.

The Company maintains margin accounts with selected counterparties to support its risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy related contracts with the respective counterparties decrease. As of June 30, 2013 and December 31, 2012, the balances in these accounts totaled $30.4 million and $16.6 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at June 30, 2013 and December 31, 2012, which would be included in Level 1 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities).

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LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources.  The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest.  The carrying amounts of such loans were $13.8 million and $13.6 million as of June 30, 2013 and December 31, 2012, respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the condensed consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.3 million as of both June 30, 2013 and December 31, 2012.  The annual amortization to interest is not material to the Company’s condensed consolidated financial statements.  The carrying amounts of these receivables approximate their fair value at June 30, 2013 and December 31, 2012, 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, 2013, approximately $14.9 million, or 30.7%, of the current and noncurrent Derivatives – Energy Related Assets are with two retail counterparties. One of these counterparties 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 a 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 $23.6 million as of both June 30, 2013 and December 31, 2012, respectively. 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 $21.1 million and $21.6 million, net of amortization, within Finance Obligation on the condensed consolidated balance sheets at June 30, 2013 and December 31, 2012, 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, 2013 and December 31, 2012, 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, 2013 and December 31, 2012, were $649.7 million and $682.3 million, respectively.  The carrying amounts of SJI's long-term debt, including current maturities, as of both June 30, 2013 and December 31, 2012, was $626.4 million.

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6. SEGMENTS OF BUSINESS:

SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. Gas Utility Operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers. Wholesale Energy Operations include SJRG’s and SJEX's activities. 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, and the installation of small commercial HVAC systems.  The Retail Energy Operations caption includes Retail Gas and Other, Retail Electric, 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 June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Operating Revenues:
Gas Utility Operations	$	66,536		$	59,177		$	240,634		$	238,613
Wholesale Energy Operations	(10,699		)	(471		)	(4,482		)	17,171
Retail Energy Operations:
Retail Gas and Other Operations	24,585			13,600			58,698			31,792
Retail Electric Operations	31,419			38,365			62,148			88,552
On-Site Energy Production	9,965			9,356			19,059			17,257
Appliance Service Operations	3,133			3,578			6,441			6,860
Subtotal Retail Energy Operations	69,102			64,899			146,346			144,461
Corporate & Services	7,362			6,331			15,842			13,045
Subtotal	132,301			129,936			398,340			413,290
Intersegment Sales	(9,709		)	(8,023		)	(20,118		)	(16,545		)
Total Operating Revenues	$	122,592		$	121,913		$	378,222		$	396,745

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	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Operating Income:
Gas Utility Operations	$	8,069		$	7,465		$	65,864		$	66,320
Wholesale Energy Operations	(19,200		)	(2,843		)	(24,357		)	7,829
Retail Energy Operations:
Retail Gas and Other Operations	(160		)	(395		)	(132		)	(547		)
Retail Electric Operations	(337		)	5,110			127			10,054
On-Site Energy Production	268			684			(905		)	346
Appliance Service Operations	799			222			785			(219		)
Subtotal Retail Energy Operations	570			5,621			(125		)	9,634
Corporate and Services	(32		)	14			4			(18		)
Total Operating (Loss) Income	$	(10,593	)	$	10,257		$	41,386		$	83,765
Depreciation and Amortization:
Gas Utility Operations	$	12,929		$	11,130		$	23,953		$	22,092
Wholesale Energy Operations	55			64			106			117
Retail Energy Operations:
Retail Gas and Other Operations	21			23			43			31
On-Site Energy Production	3,958			2,722			6,970			4,726
Appliance Service Operations	72			78			146			162
Subtotal Retail Energy Operations	4,051			2,823			7,159			4,919
Corporate and Services	221			171			446			335
Total Depreciation and Amortization	$	17,256		$	14,188		$	31,664		$	27,463
Interest Charges:
Gas Utility Operations	$	2,789		$	3,771		$	5,750		$	7,960
Wholesale Energy Operations	33			72			85			158
Retail Energy Operations:
Retail Gas and Other Operations	67			13			143			51
On-Site Energy Production	307			1,215			1,710			2,234
Subtotal Retail Energy Operations	374			1,228			1,853			2,285
Corporate and Services	1,212			837			2,720			1,558
Subtotal	4,408			5,908			10,408			11,961
Intersegment Borrowings	(988		)	(713		)	(2,280		)	(1,273		)
Total Interest Charges	$	3,420		$	5,195		$	8,128		$	10,688
Income Taxes:
Gas Utility Operations	$	2,269		$	1,887		$	23,040		$	22,864
Wholesale Energy Operations	(7,710		)	(1,028		)	(9,691		)	2,953
Retail Energy Operations:
Retail Gas and Other Operations	(52		)	(90		)	220			94
Retail Electric Operations	(139		)	2,087			51			4,107
On-Site Energy Production	(6,466		)	(4,056		)	(18,030		)	(15,230		)
Appliance Service Operations	338			109			342			(54		)
Subtotal Retail Energy Operations	(6,319		)	(1,950		)	(17,417		)	(11,083		)
Corporate and Services	128			19			208			78
Total Income Tax (Benefit) Expense	$	(11,632	)	$	(1,072	)	$	(3,860	)	$	14,812

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	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
Property Additions:
Gas Utility Operations	$	44,764	$	40,220	$	81,806	$	80,876
Wholesale Energy Operations	25		8		34		12
Retail Energy Operations:
Retail Gas and Other Operations	35		50		37		103
On-Site Energy Production	14,949		5,705		17,526		11,002
Appliance Service Operations	—		2		—		2
Subtotal Retail Energy Operations	14,984		5,757		17,563		11,107
Corporate and Services	1,126		1,254		1,864		1,659
Total Property Additions	$	60,899	$	47,239	$	101,267	$	93,654

	June 30, 2013			December 31, 2012
Identifiable Assets (See Note 1):
Gas Utility Operations	$	1,834,645		$	1,786,459
Wholesale Energy Operations	250,792			204,358
Retail Energy Operations:
Retail Gas and Other Operations	32,152			39,481
Retail Electric Operations	28,528			21,919
On-Site Energy Production	472,603			543,416
Appliance Service Operations	2,748			3,244
Subtotal Retail Energy Operations	536,031			608,060
Discontinued Operations	1,886			78
Corporate and Services	295,085			337,010
Intersegment Assets	(263,942		)	(304,525		)
Total Identifiable Assets	$	2,654,497		$	2,631,440

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7. RATES AND REGULATORY ACTIONS:

SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). In January 2013, the BPU approved an extension of the Company's Energy Efficiency Program (“EEP”) to June 30, 2013 and approved additional investments of up to $2.5 million. In June 2013, the BPU approved a further extension of SJG's EEP through June 2015 and authorized incremental investments totaling $24.0 million. The costs and returns associated with the EEP program investments will continue to be recovered through the Company's Energy Efficiency Tracker (“EET”).

Also in June 2013, SJG filed its annual EET petition requesting additional revenues to recover the costs of, and its allowed return on, prior investments associated with the EEP programs. This petition is currently pending.

In January 2013, SJG credited the accounts of SJG's periodic Basic Gas Supply Service (BGSS) customers with refunds totaling $9.4 million due to gas costs that were lower than projected.

In July 2012, SJG filed a petition to implement a five-year, $250.0 million Accelerated Infrastructure Replacement Program (“AIRP”). SJG proposed spending an incremental $50.0 million per year on the accelerated replacement of its cast iron and bare steel main and service infrastructure and was seeking a return on program investments as it had under prior Capital Investment Recovery Tracker ("CIRT") programs. SJG's CIRT III program expired on December 31, 2012. In February 2013, the parties executed a Stipulation agreeing to $35.3 million per year of incremental capital spending for four years, totaling $141.2 million under the AIRP. The BPU approved the Stipulation in February 2013.

In March 2013, SJG filed a joint petition with another utility requesting modifications to, and the continuation of, the Conservation Incentive Plan (“CIP”) program effective October 1, 2013. This petition is currently pending.

In May 2013, SJG made its annual BGSS and CIP filing requesting a $17.9 million decrease in annual revenues. This petition is currently pending.

In October 2012 SJG filed a petition requesting a $13.2 million increase in annual revenues by rolling $110.6 million of CIRT I, II and III investments into base rates. In May 2013, SJG filed a supplemental petition requesting to roll an additional $6.9 million of CIRT III investments into base rates, for a total annual revenue increase of $15.5 million related to $117.5 millionof CIRT investments made since our last base rate case in 2010. This petition is currently pending.

In June 2013, SJG filed a petition requesting deferral of incremental operating and maintenance expenses incurred due to Superstorm Sandy. These costs totaled $0.7 million and are expected to be recovered in SJG's next base rate case. This petition is currently pending.

There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2012. See Note 10 to the Consolidated Financial Statements in Item 8 of SJI's Annual Report on Form 10-K as of December 31, 2012.

8. REGULATORY ASSETS & REGULATORY LIABILITIES:

There have been no significant changes to the nature of the Company’s regulatory assets and liabilities since December 31, 2012 which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012.

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Regulatory Assets consisted of the following items (in thousands):

	June 30, 2013		December 31, 2012
Environmental Remediation Costs:
Expended - Net	$	30,387	$	37,892
Liability for Future Expenditures	110,148		107,410
Deferred Asset Retirement Obligation Costs	30,594		30,199
Deferred Pension and Other Postretirement Benefit Costs	95,897		95,897
Conservation Incentive Program Receivable	11,824		31,686
Societal Benefit Costs Receivable	12,502		12,801
Premium for Early Retirement of Debt	997		1,075
Deferred Interest Rate Contracts	5,164		7,761
Energy Efficiency Tracker	11,949		12,306
Pipeline Supplier Service Charges	7,938		8,771
Other Regulatory Assets	9,006		6,858
Total Regulatory Assets	$	326,406	$	352,656

CONSERVATION INCENTIVE PROGRAM (CIP) RECEIVABLE – The decrease in this receivable is primarily the result of colder weather experienced in the region during the 2012-2013 winter season compared with the prior winter season. The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. 

Regulatory Liabilities consisted of the following items (in thousands):

	June 30, 2013		December 31, 2012
Excess Plant Removal Costs	$	42,673	$	45,593
Deferred Revenues - Net	14,693		10,924
Other Regulatory Liabilities	3,249		—
Total Regulatory Liabilities	$	60,615	$	56,517

DEFERRED REVENUES – NET – Over/under collections of gas costs are monitored through SJG’s BGSS mechanism.  Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability.  Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval.  The BGSS increased from a $10.9 million regulatory liability at December 31, 2012 to a $14.7 million regulatory liability at June 30, 2013, primarily due to gas costs recovered from customers exceeding the actual cost of the commodity. SJG typically overcollects during the winter season when throughput is high and undercollects during the summer season when throughput is low.

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9. PENSION AND OTHER POSTRETIREMENT BENEFITS:

For the three and six months ended June 30, 2013 and 2012, 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 June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Service Cost	$	1,332		$	1,078		$	2,710		$	2,267
Interest Cost	2,387			2,412			4,719			4,811
Expected Return on Plan Assets	(2,968		)	(2,411		)	(5,957		)	(5,171		)
Amortizations:
Prior Service Cost	62			63			125			125
Actuarial Loss	2,332			2,060			4,503			3,815
Net Periodic Benefit Cost	3,145			3,202			6,100			5,847
Capitalized Benefit Costs	(1,268		)	(1,228		)	(2,435		)	(2,207		)
Total Net Periodic Benefit Expense	$	1,877		$	1,974		$	3,665		$	3,640

	Other Postretirement Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Service Cost	$	259		$	225		$	570		$	518
Interest Cost	665			733			1,365			1,501
Expected Return on Plan Assets	(601		)	(494		)	(1,189		)	(1,053		)
Amortizations:
Prior Service Credits	(71		)	(71		)	(142		)	(142		)
Actuarial Loss	410			482			869			862
Net Periodic Benefit Cost	662			875			1,473			1,686
Capitalized Benefit Costs	(248		)	(329		)	(570		)	(631		)
Total Net Periodic Benefit Expense	$	414		$	546		$	903		$	1,055

Capitalized benefit costs reflected in the table above relate to SJG’s construction program.

SJI contributed $12.7 million and $25.0 million to the pension plans in January 2013 and 2012, respectively. No additional contributions are expected to be made to the pension plans during 2013. Payments related to the unfunded supplemental executive retirement plan (SERP) are expected to approximate $1.3 million in 2013. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred.

See Note 12 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012, for additional information related to SJI’s pension and other postretirement benefits.

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10. UNUSED LINES OF CREDIT:

Credit facilities and available liquidity as of June 30, 2013 were as follows (in thousands):

Company	Total Facility		Usage		Available Liquidity		Expiration Date
SJG:
Commercial Paper Program/Revolving Credit Facility	$	200,000	$	93,000	$	107,000	May 2015
Uncommitted Bank Lines (B)	10,000		—		10,000		August 2013
Total SJG	210,000		93,000		117,000
SJI:
Revolving Credit Facility	$	400,000	$	180,300	$	219,700	February 2018 (A)
Term Line of Credit	50,000		50,000		—		November 2013
Total SJI	450,000		230,300		219,700
Total	$	660,000	$	323,300	$	336,700

(A) Includes letters of credit outstanding in the amount of $27.6 million.

(B) Although there can be no assurances, SJG anticipates renewing the remaining line of credit during the third quarter 2013.

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 0.98% and 0.95% at June 30, 2013 and 2012, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2013 and 2012 were $275.3 million and $376.2 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2013 and 2012 were $369.5 million and $462.2 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, 2013.

SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million.  The notes  have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes.  SJG uses the commercial paper program in tandem with the $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.

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11. COMMITMENTS AND CONTINGENCIES:

GUARANTEES — The Company has recorded a liability of $0.3 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, 2013 for the fair value of the following guarantees:

In April 2007, SJI guaranteed certain obligations of LVE Energy Partners, LLC (LVE), an unconsolidated joint venture in which Marina has a 50% equity interest.  LVE entered into a 25-year contract with a resort developer to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.  LVE began construction of the facility in 2007 and expected to provide full energy service in 2010 when the resort was originally scheduled to be completed.  LVE suspended construction of the district energy system and central energy center in January 2009 after the resort developer’s announcement that it was delaying the completion of construction of the resort.

In March 2013, the resort developer purchased substantially all of the assets of LVE. As a result, the guarantees provided by SJI of certain performance obligations of LVE under the operating agreements between LVE and the resort developer were canceled.

During the six months ended June 30, 2013, the Company received $57.6 million of repayments of advances from LVE. As of June 30, 2013, the Company had remaining unsecured Notes Receivable - Affiliate of approximately $7.0 million due from LVE on the condensed consolidated balance sheets related to this project. During 2013, SJI provided support to LVE of approximately $1.8 million to cover interest and other project related costs.

As a result of the sale of substantially all of the assets, management has evaluated the investment in LVE and concluded that the fair value of this investment continues to be in excess of the carrying value as of June 30, 2013.

SJI and its joint venture partner have guaranteed the repayment of interest rate derivative contracts held by LVE which mature in November 2013. As of June 30, 2013 the amount required to satisfy these contracts is approximately $3.2 million. LVE is expected to have sufficient resources to satisfy these interest rate derivative contracts upon the liquidation of its remaining assets. 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 this guarantee.

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 February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 20 year contract with a developer to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012 and as a result, ACR is providing full energy services to the complex. Marina and its joint venture partner have agreed to provide a $5.0 million letter of credit to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI to or on behalf of ACR.

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In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, of 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 is expected to be completed during the second half of 2013. Marina and its joint venture partner are obligated to make capital contributions to UMM, through Energenic, totaling approximately $10.0 million. In addition, SJI has guaranteed certain obligations of UMM under the operating and lease agreements between UMM and the university, for the terms of the agreements, commencing with the first year of operations. SJI has guaranteed up to $2.2 million for the first year. This amount is adjusted each year based upon the Consumer Price Index. SJI has also guaranteed certain construction obligations of UMM during the construction period, the majority of which are supported by a surety bond. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.

As of June 30, 2013, SJI had issued $5.1 million of guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.

COLLECTIVE BARGAINING AGREEMENTS— Unionized personnel represent approximately 45.0% of our workforce at June 30, 2013. 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 employees represented by the IBEW operate under a collective bargaining agreement that runs through February 28, 2017. SJESP employees represented by the IBEW operate under a collective bargaining agreement that runs through February 28, 2014. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that expire in August 2014.

STANDBY LETTERS OF CREDIT — As of June 30, 2013, SJI provided $27.6 million of standby letters of credit through SJI’s revolving credit facility to enable SJE to market retail electricity and for various construction activities. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.  

PENDING LITIGATION — The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.2 million related to all claims in the aggregate as of both June 30, 2013 and December 31, 2012. 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, 2012 as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012.

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12. 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, 2013, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 17.8 MMdts (1 MMdts = one million decatherms) of expected future purchases of natural gas, 24.2 MMdts of expected future sales of natural gas, 1.3 MMmwh (1 MMmwh = one million megawatt hours) of expected future purchases of electricity and 1.2 MMmwh of expected future sales of electricity. In addition to these derivative contracts, the Company had basis and index related purchase and sales contracts totaling 77.4 MMdts.  The value of these contracts are not significant as of June 30, 2013. 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 on the condensed 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 other significant changes to the Company’s active interest rate swaps since December 31, 2012 which are described in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012.

The fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of June 30, 2013 and December 31, 2012, are as follows (in thousands):

Derivatives not designated as hedging instruments under GAAP	June 30, 2013				December 31, 2012
	Assets		Liabilities		Assets		Liabilities
Energy related commodity contracts:
Derivatives – Energy Related – Current	$	33,826	$	37,979	$	24,242	$	23,828
Derivatives – Energy Related – Non-Current	14,642		25,563		12,297		5,403
Interest rate contracts:
Derivatives - Other - Non-Current	—		9,091		—		13,462
Total derivatives not designated as hedging instruments under GAAP	48,468		72,633		36,539		42,693
Total Derivatives	$	48,468	$	72,633	$	36,539	$	42,693

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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, 2013 and December 31, 2012, information related to these offsetting arrangements were as follows (in thousands):

As of June 30, 2013
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	48,468		$	—	$	48,468		$	(10,162	)	(A)	$	—	$	38,306
Derivatives - Energy Related Liabilities	$	(63,542	)	$	—	$	(63,542	)	$	10,162		(B)	$	24,078	$	(29,302	)
Derivatives - Other	$	(9,091	)	$	—	$	(9,091	)	$	—			$	—	$	(9,091	)

As of December 31, 2012
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	$	36,539		$	—	$	36,539		$	(12,975	)	(A)	$	—	$	23,564
Derivatives - Energy Related Liabilities	$	(29,231	)	$	—	$	(29,231	)	$	12,975		(B)	$	6,347	$	(9,909	)
Derivatives - Other	$	(13,462	)	$	—	$	(13,462	)	$	—			$	—	$	(13,462	)

(A) The balances at June 30, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at June 30, 2013 and December 31, 2012 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, 2013 and 2012 are as follows (in thousands):

	Three Months Ended June 30,						Six Months Ended June 30,
Derivatives in Cash Flow Hedging Relationships	2013			2012			2013			2012
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$	—		$	(888	)	$	—		$	(752	)
Losses reclassified from AOCL into income (a)	$	(112	)	$	(183	)	$	(224	)	$	(370	)
Gains (losses) recognized in income on ineffective portion (a)	—			—			—			—

(a) Included in Interest Charges

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	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments under GAAP	2013			2012		2013			2012
(Losses) gains on energy related commodity contracts (a)	$	(16,722	)	$	3,308	$	(23,771	)	$	10,279
Gains on interest rate contracts (b)	1,250			84		1,775			220
Total	$	(15,472	)	$	3,392	$	(21,996	)	$	10,499

(a)  Included in Operating Revenues - Non Utility

(b)  Included in Interest Charges

Net realized gains of $1.3 million and losses of$5.7 million for the three months ended June 30, 2013 and 2012, respectively, and losses of $0.2 million and $10.7 million for the six months ended June 30, 2013 and 2012, respectively, associated with SJG’s energy-related financial commodity contracts are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy related financial commodity contracts are deferred in Regulatory Assets or Liabilities and there is no impact to earnings.

Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on June 30, 2013, is $29.5 million.   If the credit-risk-related contingent features underlying these agreements were triggered on June 30, 2013, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $25.1 million after offsetting asset positions with the same counterparties under master netting arrangements.

13. 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.

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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, 2013	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,859	$	7,859	$	—	$	—
Derivatives – Energy Related Assets (B)	48,468		6,444		17,811		24,213
	$	56,327	$	14,303	$	17,811	$	24,213
Liabilities
Derivatives – Energy Related Liabilities (B)	$	63,542	$	4,065	$	26,749	$	32,728
Derivatives – Other (C)	9,091		—		9,091		—
	$	72,633	$	4,065	$	35,840	$	32,728

As of December 31, 2012	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,538	$	787	$	6,751	$	—
Derivatives – Energy Related Assets (B)	36,539		9,404		16,205		10,930
	$	44,077	$	10,191	$	22,956	$	10,930
Liabilities
Derivatives – Energy Related Liabilities (B)	$	29,231	$	5,399	$	15,664	$	8,168
Derivatives – Other (C)	13,462		—		13,462		—
	$	42,693	$	5,399	$	29,126	$	8,168

(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.

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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 are 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 are 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, 2013		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$17,019	$28,069	Discounted Cash Flow	Forward price (per dt)	$(1.20) - $3.58 [$(0.49)]
Forward Contract - Electric	$7,194	$4,659	Discounted Cash Flow	Fixed electric load profile (on-peak)	19.72% - 100.00% [60.44%]
				Fixed electric load profile (off-peak)	0.00% - 80.28% [39.56%]

Type	Fair Value at December 31, 2012				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	4,340	$	4,986	Discounted Cash Flow	Forward price (per dt)	$(0.35) - $2.92 [$(0.12)]
Forward Contract - Electric	$	6,590	$	3,182	Discounted Cash Flow	Fixed electric load profile (on-peak)	21.62% - 100.00% [53.64%]
						Fixed electric load profile (off-peak)	0.00% - 78.38% [46.36%]

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The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and six months ended June 30, 2013 and 2012, using significant unobservable inputs (Level 3), are as follows (in thousands):

	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
Balance at beginning of period	$	1,627		$	2,762
Total losses realized/unrealized included in earnings	(12,022		)	(12,723		)
Transfers in/(out) of Level 3 (A)	928			928
Settlements	952			518
Balance at June 30	$	(8,515	)	$	(8,515	)

(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, 2013, $0.9 million of net derivatives assets were transferred from Level 2 to Level 3, due to decreased observability of market data. The transfer was recognized as of the end of the second quarter.

	Three Months Ended June 30, 2012			Six Months Ended June 30, 2012
Balance at beginning of period	(1,958		)	(5,958		)
Total losses realized/unrealized included in earnings	3,306			3,475
Settlements	1,730			5,561
Balance at June 30	$	3,078		$	3,078

Total losses for 2013 included in earnings that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of June 30, 2013, is $(12.0) million.  These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

14. LONG-TERM DEBT:

In 2011, SJG received approval from the BPU to issue up to $200.0 million in long-term debt under its Medium Term Note program by September 2014. At June 30, 2013, $80.0 million was available under this program.

In February 2012, SJG called its $35.0 million, 7.70% Medium Term Notes due April 2027 at par plus a 2.0% premium. The early redemption occurred concurrently with the issuance in April 2012 of $35.0 million, 3.74% Series D Medium Term Notes due April 2032.

The Company did not issue or retire any long-term debt during the six months ended June 30, 2013.

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15. 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, 2013 (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, 2013 (a)	$	(23,437	)	$	(2,896	)	$	20		$	14	$	(26,299	)
Other comprehensive income before reclassifications	—			—			(23		)	—		(23		)
Amounts reclassified from AOCL (b)	—			66			—			22		88
Net current period other comprehensive income (loss)	—			66			(23		)	22		65
Balance at June 30, 2013 (a)	$	(23,437	)	$	(2,830	)	$	(3	)	$	36	$	(26,234	)

	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, 2013 (a)	$	(23,437	)	$	(2,962	)	$	294		$	(5,000	)	$	(31,105	)
Other comprehensive income before reclassifications	—			—			192			—			192
Amounts reclassified from AOCL (b)	—			132			(489		)	5,036			4,679
Net current period other comprehensive income (loss)	—			132			(297		)	5,036			4,871
Balance at June 30, 2013 (a)	$	(23,437	)	$	(2,830	)	$	(3	)	$	36		$	(26,234	)

(a) Determined using a combined statutory tax rate of 41%.

(b) See table below.

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The following table provides details about reclassifications out of AOCL for the three and six months ended June 30, 2013:

	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Consolidated Statements of Income
	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	112		$	224		Interest Charges
Income Taxes	(46		)	(92		)	Income Taxes (a)
	$	66		$	132
Unrealized Gain on Available-for-Sale Securities	$	—		$	(827	)	Other Income
Income Taxes	—			338			Income Taxes (a)
	$	—		$	(489	)
Loss of Affiliated Companies	$	35		$	8,511		Equity in Loss of Affiliated Companies
Income Taxes	(13		)	(3,475		)	Income Taxes (a)
	$	22		$	5,036
Losses from reclassifications for the period net of tax	$	88		$	4,679

16. SUBSEQUENT EVENT:

In July 2013, SJG redeemed at par $10.5 million of 4.46% Medium Term Notes issued in July 2003.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Forward-Looking Statements and Risk Factors— Certain statements contained in this Quarterly Report may qualify as “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical fact included in this Report should be considered forward-looking statements made in good faith and are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. Words such as “anticipate”, “believe”, “expect”, “estimate”, “forecast”, “goal”, “intend”, “objective”, “plan”, “project”, “seek”, “strategy” and similar expressions are intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed or implied in the statements. These risks and uncertainties include, but are not limited to, the following: general economic conditions on an international, national, state and local level; weather conditions in our marketing areas; changes in commodity costs; changes in the availability of natural gas; “non-routine” or “extraordinary” disruptions in our distribution system; regulatory, legislative and court decisions; competition; the availability and cost of capital; costs and effects of legal proceedings and environmental liabilities; the failure of customers, suppliers or business partners to fulfill their contractual obligations; and changes in business strategies.

A discussion of these and other risks and uncertainties may be found in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012 and in other filings made by us with the Securities and Exchange Commission (SEC). These cautionary statements should not be construed by you to be exhaustive and they are made only as of the date of this Quarterly Report on Form 10-Q, or in any document incorporated by reference, at the date of such document. While South Jersey Industries, Inc. (SJI or the Company) believes these forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. Further, SJI undertakes no obligation to update or revise any of its forward-looking statements, whether as a result of new information, future events or otherwise.

Critical Accounting Policies — Estimates and Assumptions— Management must make estimates and assumptions that affect the amounts reported in the condensed consolidated financial statements and related disclosures. Actual results could differ from those estimates. Five types of transactions presented in our condensed consolidated financial statements require a significant amount of judgment and estimation. These relate to regulatory accounting, derivatives, environmental remediation costs, pension and other postretirement employee benefit costs, and revenue recognition. A discussion of these estimates and assumptions may be found in our Form 10-K for the year ended December 31, 2012.

New Accounting Pronouncements— See detailed discussions concerning New Accounting Pronouncements and their impact on SJI in Note 1 to the condensed consolidated financial statements.

Regulatory Actions—Other than the changes discussed in Note 7 to the condensed consolidated financial statements, there have been no significant regulatory actions since December 31, 2012. See detailed discussion concerning Regulatory Actions in Note 10 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012.

Environmental Remediation—There have been no significant changes to the status of the Company’s environmental remediation efforts since December 31, 2012. See detailed discussion concerning Environmental Remediation in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012.

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RESULTS OF OPERATIONS:

SJI operates in several different reportable operating segments. Gas Utility Operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers. Wholesale Energy Operations include the activities of South Jersey Resources Group, LLC (SJRG) and South Jersey Exploration, LLC (SJEX). South Jersey Energy Company (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 Energy, LLC ("Marina's") thermal energy facility and other energy-related projects. Appliance Service Operations includes South Jersey Energy Service Plus, LLC (SJESP’s) servicing of appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.  The Retail Energy Operations caption includes Retail Gas and Other, Retail Electric, On-Site Energy Production and Appliance Service Operations.

Net Income for the three months ended June 30, 2013 decreased $9.4 million to $0.9 million compared with the same period in 2012 primarily as a result of the following:

• The income contribution from SJRG for the three months ended June 30, 2013 decreased $9.6 million to a net loss of $11.3 million due primarily to the change in unrealized gains and losses on derivatives used by SJRG to mitigate natural gas commodity price risk, as discussed under Operating Revenues - Nonutility below, along with lower storage and daily trading margins as described in Gross Margin - Nonutility below.

• The income contribution from SJE for the three months ended June 30, 2013 decreased $3.2 million to a net loss of $0.3 million due primarily to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on electric as discussed under Operating Revenues – Nonutility below.

• The income contribution from Marina for the three months ended June 30, 2013 increased $1.8 million to $7.8 million due primarily to the impact of the investment tax credit available on renewable energy facilities.

• The income contribution from SJG for the three months ended June 30, 2013 increased $0.6 million to $3.8 million due primarily to increases in the accelerated infrastructure programs and customer growth over the prior year.

Net Income for the six months ended June 30, 2013 decreased $20.7 million to $43.8 million compared with the same period in 2012 primarily as a result of the following:

• The income contribution from SJRG for the six months ended June 30, 2013 decreased $18.9 million to a net loss of $14.3 million due primarily to the change in unrealized gains and losses on derivatives used by SJRG to mitigate natural gas commodity price risk, as discussed under Operating Revenues - Nonutility below, along with lower storage and daily trading margins as described in Gross Margin - Nonutility below.

• The income contribution from SJE for the six months ended June 30, 2013 decreased $5.7 million to $0.4 million due primarily to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on electric as discussed under Operating Revenues – Nonutility below.

• The income contribution from Marina for the six months ended June 30, 2013 increased $1.4 million to $17.7 million due primarily to the impact of the investment tax credit available on renewable energy facilities.

• The income contribution from SJG for the six months ended June 30, 2013 increased $1.1 million to $39.3 million due primarily to increases in the accelerated infrastructure programs and customer growth over the prior year.

A significant portion of the volatility in operating results is due to the impact of the accounting methods associated with SJI’s derivative activities. The Company uses derivatives to limit its exposure to market risk on transactions to buy, sell, transport and store natural gas and to buy and sell retail electricity. The Company also uses derivatives to limit its exposure to increasing interest rates on variable-rate debt.

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The types of transactions that cause the most significant volatility in operating results are as follows:

• SJRG purchases and holds natural gas in storage to earn a profit margin from its ultimate sale in the future. SJRG uses derivatives to mitigate commodity price risk in order to substantially lock-in the profit margin that will ultimately be realized. However, gas stored in inventory is accounted for at the lower of average cost or market; the derivatives used to reduce the risk associated with a change in the value of the inventory are accounted for at fair value, with changes in fair value recorded in operating results in the period of change. As a result, earnings are subject to volatility as the market price of derivatives change, even when the underlying hedged value of the inventory is unchanged. Additionally, volatility in earnings is created when realized gains and losses on derivatives used to mitigate commodity price risk on expected future purchases of gas in storage are recognized in earnings when the derivatives settle, but the cost of the related gas in storage is not recognized in earnings until the period of withdrawal. This volatility can be significant from period to period. Over time, gains or losses on sale of gas in storage will be offset by losses or gains on the derivatives, resulting in the realization of the profit margin expected when the transactions were initiated.

• SJE uses forward contracts to mitigate commodity price risk on fixed price electric contracts with customers. In accordance with accounting principles generally accepted in the United States of America (GAAP), the forward contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. Several related customer contracts are not considered derivatives and therefore are not recorded in earnings until the electricity is delivered. As a result, earnings are subject to volatility as the market price of the forward contracts change, even when the underlying hedged value of the customer contract is unchanged. Over time, gains or losses on the sale of the fixed price electric under contract will be offset by losses or gains on the forward contracts, resulting in the realization of the profit margin expected when the transactions were initiated.

As a result, management also uses the non-generally accepted accounting principles (“non-GAAP”) financial measures of Economic Earnings, Economic Earnings per share, Non-Utility Economic Earnings, Wholesale Energy Economic Earnings and Retail Energy Economic Earnings when evaluating the results of operations for its nonutility operations. These non-GAAP financial measures should not be considered as an alternative to GAAP measures, such as net income, operating income, earnings per share from continuing operations or any other GAAP measure of liquidity or financial performance.

We define Economic Earnings as: Income from continuing operations, (1) less the change in unrealized gains and plus the change in unrealized losses, as applicable and in each case after tax, on all derivative transactions, and (2) less realized gains and plus realized losses, as applicable and in each case after tax, on all commodity derivative transactions attributed to expected purchases of gas in storage to match the recognition of these gains and losses with the recognition of the related cost of the gas in storage in the period of withdrawal, and (3) less the impact of transactions or contractual arrangements where the true economic impact will be realized in a future period. With respect to the third part of the definition of Economic Earnings, for the three and six months ended June 30, 2013:

• Economic Earnings excludes a $0.1 million gain and a $0.8 million loss (net of tax), respectively, from affiliated companies, not part of ongoing operations. This adjustment is the result of the termination of the contract at LVE Energy Partners, LLC (see Note 11 to the condensed consolidated financial statements) and is being excluded because substantially all of the assets of LVE have been sold and LVE is no longer considered part of the ongoing operations of the Company.

• Economic Earnings includes additional depreciation expense on a solar generating facility. During 2012 an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and therefore the related reduction in depreciation expense is being added back.

Economic Earnings is a significant performance metric used by our management to indicate the amount and timing of income from continuing operations that we expect to earn after taking into account the impact of derivative instruments on the related transactions and transactions or contractual arrangements where the true economic impact will be realized in a future period. Specifically, we believe that this financial measure indicates to investors the profitability of the entire derivative related transaction and not just the portion that is subject to mark-to-market valuation under GAAP. Considering only the change in market value on the derivative side of the transaction can produce a false sense as to the ultimate profitability of the total transaction as no change in value is reflected for the non-derivative portion of the transaction.

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Economic Earnings for the three months ended June 30, 2013 increased $1.3 million to $9.9 million compared with the same period in 2012, primarily as a result of the following:

• The income contribution from Marina for the three months ended June 30, 2013 increased $1.3 million to $7.0 million due primarily to the impact of the investment tax credit available on renewable energy facilities.

• The income contribution from SJG for the three months ended June 30, 2013 increased $0.6 million to $3.8 million due primarily to increases in the accelerated infrastructure programs and customer growth over the prior year.

• The income contribution from SJRG for the three months ended June 30, 2013 decreased $1.5 million to a net loss of $2.2 million due to lower storage and daily trading margins as described in Gross Margin - Nonutility below.

Economic Earnings for the six months ended June 30, 2013 decreased $0.3 million to $58.3 million compared with the same period in 2012, primarily as a result of the following:

• The income contribution from SJRG for the six months ended June 30, 2013 decreased $4.8 million to a net loss of $1.2 million due to lower storage and daily trading margins as described in Gross Margin - Nonutility below.

• The income contribution from Marina for the six months ended June 30, 2013 increased $1.7 million to $17.7 million due primarily to the impact of the investment tax credit available on renewable energy facilities.

• The income contribution from SJG for the six months ended June 30, 2013 increased $1.1 million to $39.3 million due primarily to increases in the accelerated infrastructure programs and customer growth over the prior year.

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The following table presents a reconciliation of our income from continuing operations and earnings per share from continuing operations to Economic Earnings and Economic Earnings per share for the three and six months ended June 30 (in thousands except per share data):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Income from Continuing Operations	$	916		$	10,832		$	44,253		$	65,043
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives	9,210			(2,267		)	13,308			(6,465		)
Realized (Gains)/Losses on Inventory Injection Hedges	(115		)	52			5			76
Net (Gain) Loss from Affiliated Companies, Not Part of Ongoing Operations (A)	(101		)	—			805			—
Other (B)	(25		)	—			(50		)	—
Economic Earnings	$	9,885		$	8,617		$	58,321		$	58,654
Earnings per Share from Continuing Operations	$	0.03		$	0.36		$	1.39		$	2.14
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives	0.29			(0.08		)	0.42			(0.21		)
Realized (Gains)/Losses on Inventory Injection Hedges	(0.01		)	—			—			—
Net (Gain) Loss from Affiliated Companies, Not Part of Ongoing Operations (A)	—			—			0.02			—
Economic Earnings per Share	$	0.31		$	0.28		$	1.83		$	1.93
Non-Utility Income from Continuing Operations	$	(2,906	)	$	7,596		$	4,917		$	26,769
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives	9,210			(2,267		)	13,308			(6,465		)
Realized (Gains)/Losses on Inventory Injection Hedges	(115		)	52			5			76
Net (Gain) Loss from Affiliated Companies, Not Part of Ongoing Operations (A)	(101		)	—			805			—
Other (B)	(25		)	—			(50		)	—
Non-Utility Economic Earnings	$	6,063		$	5,381		$	18,985		$	20,380
Wholesale Energy Income from Continuing Operations	$	(11,164	)	$	(1,489	)	$	(14,032	)	$	4,309
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives	9,269			967			13,231			(914		)
Realized (Gains)/Losses on Inventory Injection Hedges	(115		)	52			5			76
Wholesale Energy Economic Earnings	$	(2,010	)	$	(470	)	$	(796	)	$	3,471
Retail Energy Income from Continuing Operations	$	8,258		$	9,085		$	18,949		$	22,460
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives	(59		)	(3,234		)	77			(5,551		)
Net (Gain) Loss from Affiliated Companies, Not Part of Ongoing Operations (A)	(101		)	—			805			—
Other (B)	(25		)	—			(50		)	—
Retail Energy Economic Earnings	$	8,073		$	5,851		$	19,781		$	16,909

(A) Resulting from the termination of the contract at LVE Energy Partners, LLC to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.

(B) Represents additional depreciation expense within Economic Earnings on a solar generating facility. During 2012 an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and therefore the related reduction in depreciation expense is being added back.

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The effect of derivative instruments not designated as hedging instruments under GAAP in the condensed consolidated statements of income (see Note 12 to the condensed consolidated financial statements) is as follows (gains (losses) in thousands):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
(Losses) gains on energy related commodity contracts	$	(16,722	)	$	3,308		$	(23,771	)	$	10,279
Gains on interest rate contracts	1,250			84			1,775			220
Total before income taxes	(15,472		)	3,392			(21,996		)	10,499
Income taxes (A)	6,344			(1,391		)	9,018			(4,305		)
Total after income taxes	(9,128		)	2,001			(12,978		)	6,194
Unrealized mark-to-market gains (losses) on derivatives    held by affiliated companies, net of tax (A)	(82		)	266			(330		)	271
Total unrealized mark-to-market (losses) gains on derivatives	(9,210		)	2,267			(13,308		)	6,465
Realized gains (losses) on inventory injection hedges, net of tax (A)	115			(52		)	(5		)	(76		)
Net Gain (Loss) from Affiliated Companies, Not Part of Ongoing Operations (B)	101			—			(805		)	—
Other (C)	25			—			50			—
Total reconciling items between income from continuing    operations and economic earnings	$	(8,969	)	$	2,215		$	(14,068	)	$	6,389

(A) Determined using a combined statutory tax rate of 41%

(B) Resulting from the termination of the contract at LVE Energy Partners, LLC to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.

(C) Represents additional depreciation expense within Economic Earnings on a solar generating facility. During 2012 an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and therefore the related reduction in depreciation expense is being added back.

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The following tables summarize the composition of selected SJG data for the three and six months ended June 30 (in thousands, except for degree day data):

	Three Months Ended June 30,		Six Months Ended June 30,
	2013	2012	2013	2012
Utility Throughput – dt:
Firm Sales -
Residential	2,805	2,294	13,875	10,889
Commercial	671	638	3,187	2,617
Industrial	29	36	183	162
Cogeneration & Electric Generation	420	418	565	494
Firm Transportation -
Residential	447	274	2,075	1,240
Commercial	1,078	920	4,064	3,165
Industrial	3,161	3,064	6,728	6,494
Cogeneration & Electric Generation	1,692	1,903	3,774	4,065
Total Firm Throughput	10,303	9,547	34,451	29,126
Interruptible Sales	14	2	14	2
Interruptible Transportation	305	317	739	741
Off-System	1,454	1,080	3,167	5,551
Capacity Release	7,146	17,019	20,961	33,986
Total Throughput - Utility	19,222	27,965	59,332	69,406

	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
Utility Operating Revenues:
Firm Sales -
Residential	$	33,798	$	33,024	$	141,922	$	146,653
Commercial	7,767		7,229		31,402		29,291
Industrial	529		381		2,157		1,634
Cogeneration & Electric Generation	2,380		1,525		3,163		1,928
Firm Transportation -
Residential	3,075		2,158		12,364		8,081
Commercial	4,031		3,936		15,362		13,049
Industrial	5,374		5,188		11,318		10,608
Cogeneration & Electric Generation	1,371		1,241		3,605		3,242
Total Firm Revenues	58,325		54,682		221,293		214,486

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	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Interruptible Sales	339			42			339			50
Interruptible Transportation	375			338			915			816
Off-System	6,573			3,054			13,255			18,883
Capacity Release	687			787			4,374			3,846
Other	237			274			458			532
	66,536			59,177			240,634			238,613
Less: Intercompany Sales	(496		)	(121		)	(943		)	(355		)
Total Utility Operating Revenues	66,040			59,056			239,691			238,258
Less:
Cost of Sales - Utility (Excluding depreciation)	25,611			20,286			102,766			106,551
Conservation Recoveries*	2,748			1,540			8,072			4,842
RAC Recoveries*	2,177			1,911			4,355			3,823
EET Recoveries*	1,195			843			2,191			1,555
Revenue and Throughput Taxes	696			884			2,940			3,375
Utility Margin	$	33,613		$	33,592		$	119,367		$	118,112
Margin:
Residential	$	21,624		$	18,723		$	81,136		$	65,616
Commercial and Industrial	9,645			9,892			30,924			27,480
Cogeneration and Electric Generation	1,208			1,165			2,438			2,129
Interruptible	56			21			80			52
Off-system & Capacity Release	232			196			917			1,096
Other Revenues	499			515			765			772
Margin Before Weather Normalization & Decoupling	33,264			30,512			116,260			97,145
CIRT Mechanism	734			763			1,476			1,530
CIP Mechanism	(514		)	2,212			1,377			19,233
EET Mechanism	129			105			254			204
Utility Margin	$	33,613		$	33,592		$	119,367		$	118,112
Degree Days:	495			367			2,952			2,297

*Represents expenses for which there is a corresponding credit in operating revenues.  Therefore, such recoveries have no impact on our financial results.

Throughput - Utility - Total gas throughput decreased 8.7 MMdts, or 31.3%, for the three months ended June 30, 2013, compared with the same period in 2012.  This decrease was realized primarily in Capacity Release activity which decreased 9.9 MMdts during the three months ended June 30, 2013, as compared with the same period in 2012. In 2013, SJG entered into a new asset management agreement with a third party that allocated a significant amount of capacity for a fixed fee. This transfer of capacity rights left less available for SJG's normal release activity. In addition, SJG was releasing capacity in smaller segments ("segmenting") in 2012 based on the demand in the market at that time. While segmenting has little impact on total revenue generated from such activity, it does increase the throughput significantly. Firm throughput increased 0.8 MMdts, or 7.9%, during the three months ended June 30, 2013, compared to the same period in 2012.  This is most apparent in the heat sensitive residential and commercial markets whose throughput increased as a result of weather that was 34.9% colder for the three months ended June 30, 2013, as compared with the same period last year. Also contributing to higher firm throughput was customer growth.  The Company added 5,173 customers over the twelve month period ended June 30, 2013, which represents a growth rate of 1.5%.

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Total gas throughput decreased 10.1 MMdts, or 14.5%, for the six months ended June 30, 2013, compared with the same period in 2012. This decrease was realized primarily in the Capacity Release and OSS markets which decreased 13.0 MMdts and 2.4 MMdts, respectively, during the six months ended June 30, 2013, as compared with the same period in 2012. Due to colder weather experienced in the region during the first quarter of 2013, SJG experienced an increased demand by its firm customers, thereby creating fewer opportunities for both Capacity Release and Off-System sales outside of SJG's territory during the winter months. Also contributing to the decrease in Capacity Release throughput was the new asset management agreement and segmenting of capacity release in 2012, discussed above as part of the three month results. Firm throughput increased 5.3 MMdts, or 18.3%, during the six months ended June 30, 2013, compared to the same period in 2012. As previously stated, this is most apparent in the heat sensitive residential and commercial markets whose throughput increased as a result of weather that was 28.5% colder for the six months ended June 30, 2013, as compared with the same period last year. Also contributing to higher firm throughput was the 1.5% customer growth previously discussed.  

Conservation Incentive Program (CIP) - Utility - The effects of the CIP on SJG’s net income for the three and six months ended June 30, 2013 and 2012 and the associated weather comparisons were as follows ($’s in millions):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Net Income Benefit:
CIP – Weather Related	$	—		$	1.4		$	(0.7	)	$	7.6
CIP – Usage Related	(0.3		)	(0.1		)	1.5			3.8
Total Net Income Benefit	$	(0.3	)	$	1.3		$	0.8		$	11.4
Weather Compared to 20-Year Average	Average			31.1% warmer			1.8% Colder			23.1% warmer
Weather Compared to Prior Year	34.9% Colder			2.4% warmer			28.5% Colder			20.0% warmer

Operating Revenues  - Utility - Revenues increased $7.0 million, or 11.8%, during the three months ended June 30, 2013, compared with the same period in the prior year after eliminating intercompany transactions. Total firm revenue increased $3.6 million, or 6.7%, during the second quarter of 2013 versus the same period in 2012. As stated under "Throughput-Utility," colder weather increased firm sales volume during the second quarter which led to higher firm revenue. This was partially offset by lower gas costs being passed through to those customers, as SJG reduced its BGSS rate by 18% in October 2012. While changes in gas costs and BGSS recoveries/refunds may fluctuate from period to period, SJG does not profit from the sale of the commodity.  Therefore, corresponding fluctuations in Utility Operating Revenue or Cost of Sales have no impact on Company profitability, as further discussed below under the caption “Margin-Utility.” Higher Off-System Sales (OSS) volume, coupled with higher per unit sales prices, resulted in a $3.5 million increase in OSS revenues during the three months ended June 30, 2013, compared with the same period last year. As reflected in the Margin table above, the impact of changes in OSS and capacity release activity do not have a material impact on the earnings of SJG, as SJG is required to share 85% of the profits of such activity with the ratepayers.

Revenues increased $1.4 million, or 0.6%, during the six months ended June 30, 2013, compared with the same period in the prior year after eliminating intercompany transactions. Total firm revenue increased $6.8 million, or 3.2%, during the six months ended June 30, 2013 versus the same period in 2012. As stated under "Throughput-Utility," colder weather increased firm sales volume significantly compared with prior year; however, associated firm revenue did not increase proportionately. This is the result of lower gas costs being passed through to those customers, as SJG reduced its BGSS rate by 18% in October 2012. In addition, SJG gave a refund of $9.4 million to its periodic BGSS customers in January 2013, which further reduced revenue. As previously stated, SJG does not profit from the sale of the commodity. Therefore, corresponding fluctuations in Utility Operating Revenue or Cost of Sales have no impact on Company profitability, as further discussed below under the caption "Margin-Utility." Lower OSS volume resulted in a $5.6 million, or 29.8%, reduction in OSS revenues during the six months ended June 30, 2013, compared with the same period last year. As previously stated, the impact of changes in OSS and capacity release activity do not have a material impact on the earnings of SJG, as SJG is required to share 85% of the profits of such activity with the ratepayers.

While changes in gas costs and BGSS recoveries/refunds may fluctuate from period to period, SJG does not profit from the sale of the commodity.  Therefore, corresponding fluctuations in Operating Revenue or Cost of Sales have no impact on Company profitability, as further discussed below under the caption “Margin-Utility.”

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Operating Revenues — Nonutility -  Combined revenues for SJI’s nonutility businesses, net of intercompany transactions, decreased $6.3 million, or 10.0%, and $20.0 million, or 12.6%, for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012.

SJE’s revenues from retail gas operations, net of intercompany transactions, increased $11.0 million, or 80.9%, and $26.8 million, or 84.5%, for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Excluding the change in unrealized gains and losses recorded on forward financial contracts of $(0.3) million and $(0.8) million, revenues increased $11.3 million and $27.6 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. The increase in revenues was mainly due to an 84.4% and 49.9% increase in the average monthly New York Mercantile Exchange (NYMEX) settle price for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012, along with a 32.3% and 60.2% increase in sales volumes for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012, which was due to the impact of acquiring a retail gas marketing book in the third quarter of 2012. As of June 30, 2013 and 2012, SJE was serving 3,039 and 1,719 retail gas customers, respectively. Sales volumes totaled 5,400,332 and 4,082,663 dekatherms for the three months ended June 30, 2013 and 2012, respectively, and 13,397,585 and 8,365,065 dekatherms for the six months ended June 30, 2013 and 2012, respectively.

Market conditions continue to make it difficult to be competitive in the small commercial market. We continue to focus our marketing efforts on the pursuit of non-heat-sensitive commercial customers in an effort to mitigate price volatility and weather risk.

SJE’s revenues from retail electric operations, net of intercompany transactions, decreased $6.6 million, or 17.9%, and $25.8 million, or 30.1%, for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $5.7 million and $9.2 million, revenues decreased $0.9 million, or 2.8%, and $16.6 million, or 21.5% for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012.

A summary of SJE’s revenues from retail electricity is as follows (in millions):

	Three Months Ended June 30,								Six Months Ended June 30,
	2013		2012			Change			2013		2012			Change
SJE Retail Electric Revenue	$	30.2	$	36.8		$	(6.6	)	$	59.8	$	85.6		$	(25.8	)
Add: Unrealized Losses (Subtract: Unrealized Gains)	0.9		(4.8		)	5.7			0.8		(8.4		)	9.2
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains)	$	31.1	$	32.0		$	(0.9	)	$	60.6	$	77.2		$	(16.6	)

The decrease in revenues was mainly due to a 24.7% and 26.6% decrease in volumes for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012, mainly due to a significant school board contract that expired in the second quarter of 2012. Also contributing to the decrease was a 1.8% and 4.8% decrease in the average monthly sales price, which was driven by a lower average Locational Marginal Price (LMP) per megawatt hour. SJE uses forward financial contracts to mitigate commodity price risk on fixed price electric contracts. In accordance with GAAP, the forward financial contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. The related customer contracts are not considered derivatives and, therefore, are not recorded in earnings until the electricity is delivered. As a result, earnings are subject to volatility as the market price of the forward financial contracts change, even when the underlying hedged value of the customer contract is unchanged. Over time, gains or losses on the sale of the fixed price electric under contract will be offset by losses or gains on the forward financial contracts, resulting in the realization of the profit margin expected when the transactions were initiated. SJE serves both fixed and market-priced customers.

SJRG’s revenues from wholesale energy operations, net of intercompany transactions, decreased $10.3 million and $21.9 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $14.1 million and $23.9 million, and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $(0.3) million and $(0.1) million to align them with the related cost of inventory in the period of withdrawal, SJRG’s revenues increased $3.5 million and $1.9 million for the three and six months ended June 30, 2013 compared with the same periods in 2012.

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A summary of SJRG’s revenue for the three and six months ended June 30 is as follows (in millions):

	Three Months Ended June 30,									Six Months Ended June 30,
	2013			2012			Change			2013			2012			Change
SJRG Revenue	$	(10.8	)	$	(0.5	)	$	(10.3	)	$	(4.8	)	$	17.1		$	(21.9	)
Add: Unrealized Losses (Subtract: Unrealized Gains)	15.7			1.6			14.1			22.4			(1.5		)	23.9
Add:  Realized Losses (Subtract: Realized Gains) on Inventory Injection Hedges	(0.2		)	0.1			(0.3		)	—			0.1			(0.1		)
SJRG Revenue, Excluding Unrealized Losses (Gains) and  Realized Losses (Gains) on Inventory Injection Hedges	$	4.7		$	1.2		$	3.5		$	17.6		$	15.7		$	1.9

The increase in revenues was due mainly to an overall increase in sales volumes compared with the prior year. As discussed in Note 1 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues – Nonutility.

Revenues from on-site energy production at Marina, net of intercompany transactions, did not change significantly for the three months ended June 30, 2013, respectively, compared with the same period in 2012. Revenues from on-site energy production at Marina, net of intercompany transactions, increased $1.4 million, or 7.9%, for the six months ended June 30, 2013, respectively, compared with the same period in 2012 primarily due to higher hot water production and electricity sales at the thermal facility due to colder temperatures during the first quarter of 2013 as compared to the prior year. Revenues also increased as a result of several new renewable energy projects that began operations over the past twelve months.

Revenues from appliance service operations at SJESP, net of intercompany transactions, did not change significantly for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012.

Margin – Utility — SJG’s margin is defined as natural gas revenues less natural gas costs, regulatory rider expenses and related volumetric and revenue based energy taxes. SJG believes that margin provides a more meaningful basis for evaluating utility operations than revenues since natural gas costs, regulatory rider expenses and related energy taxes are passed through to customers, and therefore, they have no effect on margin. Natural gas costs are charged to operating expenses on the basis of therm sales at the prices approved by the New Jersey Board of Public Utilities (BPU) through SJG’s BGSS clause.

Total utility margin did not change significantly the three months ended June 30, 2013 as compared with the same period in 2012.

Total margin increased $1.3 million, or 1.1%, for the six months ended June 30, 2013, compared with the same period in 2012, primarily due to customer additions.  SJG added 5,173 customers over the 12-month period ended June 30, 2013, representing growth of 1.5% over the prior year and a corresponding increase in margin.

As reflected in the margin table and the CIP table above, the CIP protected $1.4 million, or $0.8 million after taxes, in the first six months of 2013 that would have been lost due to lower customer usage, compared with $19.2 million, or $11.4 million after taxes, during the same period last year.

Gross Margin — Nonutility —  Gross margin for the nonutility businesses is defined as revenue less all costs that are directly related to the production, selling and delivery of the Company’s products and services. These costs primarily include natural gas and electric commodity costs as well as certain payroll and related benefits. On the statements of condensed consolidated income, revenue is reflected in Operating Revenues - Nonutility and the costs are reflected in Cost of Sales - Nonutility. As discussed in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues - Nonutility.

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For the three and six months ended June 30, 2013, combined gross margins for the nonutility businesses, net of intercompany transactions, decreased $19.3 million and $37.5 million to $(5.7) million and $1.1 million, respectively, compared with the same periods in 2012. These changes were primarily due to the following:

• Gross margin from the wholesale energy operations of SJRG decreased $16.3 million and $31.8 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $14.1 million and $23.9 million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $(0.3) million and $(0.1) million to align them with the related cost of inventory in the period of withdrawal as discussed above, gross margin for SJRG decreased $2.5 million and $8.0 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. The decrease in gross margin was mainly due to lower storage and daily trading margins in 2013 as compared to the prior year, partially offset by increases in the average monthly NYMEX settle price as discussed above.

Overall, SJRG's contribution to margin from storage and transportation agreements has decreased due to market conditions and, as a result, SJRG has shed some of these agreements. However, SJRG expects to continue to add incremental margin from marketing and related opportunities in the Marcellus region, capitalizing on its established presence in the area. Future margins could fluctuate significantly due to the volatile nature of wholesale gas prices. As of June 30, 2013, SJRG had 9.7 Bcf of storage and 518,632 dts/day of transportation under contract. 

• Gross Margin from on-site energy production at Marina, net of intercompany transactions, increased $1.7 million and $2.6 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Gross margin as a percentage of Operating Revenues increased 6.4 and 4.2 percentage points for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. This was due mainly to the impact of several new, higher margin renewable energy projects added over the last twelve months.

• Gross margin from SJE’s retail gas and other operations increased $0.5 million and $1.2 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Excluding the change in unrealized gains and losses recorded on forward financial contracts of $(0.3) million and $(0.8) million, gross margins increased $0.8 million and $2.0 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts as discussed above, gross margin as a percentage of Operating Revenues increased 1.0 and 1.2 percentage points for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. This increase was due to the impact of acquiring a retail gas marketing book in the third quarter of 2012 that contained higher-margin customers.

• Gross margin from SJE’s retail electric operations decreased $5.4 million and $9.9 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts of $5.7 million and $9.2 million as discussed above, gross margin increased $0.3 million and decreased $0.7 million in the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012.  Excluding the impact of the unrealized gains/losses discussed above, gross margin as a percentage of Operating Revenues did not change significantly for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. The six month comparative period decrease is due to a significant school board contract that expired in the second quarter of 2012 (See Operating Revenues - Nonutility).

• Gross margin from appliance service operations at SJESP increased $0.3 million and $0.5 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. Gross margin as a percentage of Operating Revenues increased 13.7 and 9.4 percentage points for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012. This is due to the significant decline in personnel costs that resulted from an initiative to right-size our workforce.

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Operations Expense — A summary of net changes in operations expense for the three and six months ended June 30, follows (in thousands):

	Three Months Ended June 30, 2013 vs. 2012			Six Months Ended June 30, 2013 vs. 2012
Gas Utility Operations	$	891		$	4,378
Nonutility:
Wholesale Energy Operations	54			430
Retail Gas and Other Operations	305			764
Retail Electric Operations	24			46
On-Site Energy Production	623			1,577
Appliance Service Operations	(314		)	(521		)
Total Nonutility	692			2,296
Intercompany Eliminations and Other	(42		)	(226		)
Total Operations Expense	$	1,541		$	6,448

Gas Utility operations expense increased $0.9 million and $4.4 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012.  These increases are due to increased spending under the New Jersey Clean Energy Program and Energy Efficiency Programs. Such costs are recovered on a dollar-for-dollar basis; therefore, SJG experienced an offsetting increase in revenues during the period.

Nonutility operations expense increased $0.7 million and $2.3 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012, primarily due to additional personnel, governance and compliance costs incurred to support continued growth.

Maintenance - Changes in maintenance expense for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012, were not significant.

Depreciation - Depreciation increased $1.9 million and $3.7 million during the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012 due mainly to the increased investment in property, plant and equipment by SJG and Marina.

Energy and Other Taxes - Changes in energy and other taxes for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012, were not significant.

Other Income and Expense - Other income and expense decreased $1.0 million during the three months ended June 30, 2013 compared with the same period in 2012 primarily due to a decrease in interest income on notes receivable from affiliates. Other income and expense increased $1.0 million during the six months ended June 30, 2013 compared with the same period in 2012 primarily due to an impairment charge taken during the first quarter of 2012 at SJEX that did not recur in 2013. The impairment charge was related to lower than forecasted natural gas reserves at our shallow well investment in the Marcellus region. This was partially offset by a decrease in interest income on notes receivable from affiliates.

Interest Charges – Interest charges decreased $1.8 million and $2.6 million for the three and six months ended June 30, 2013, respectively, compared with the same periods in 2012 primarily due to less short-term borrowings as cash proceeds were received from LVE and Energenic as discussed in Note 3 to the condensed consolidated financial statements. Also contributing to the decrease is the positive impact of retiring $35.0 million of SJG's higher priced long-term debt during 2012 and higher capitalization of interest costs on construction at SJG. This is partially offset by the issuance of $115.0 million aggregate principal amount of SJI Senior Notes at the end of the second quarter 2012 and the issuance of $85.0 million of SJG Medium Term Notes during the second half of 2012.

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Income Taxes– Income tax benefit increased $10.6 million for the three months ended June 30, 2013 compared with the same period in 2012. Income taxes changed from a $14.8 million expense for the six months ended June 30, 2012 to a $3.9 million benefit for the six months ended June 30, 2013. These changes were primarily due to lower income before income taxes, along with a lower effective tax rate due to higher investment tax credits available on renewable energy facilities at Marina in the first six months of 2013 as compared to the prior year.

Equity in Earnings of Affiliated Companies– Equity in earnings of affiliated companies decreased $0.4 million and $0.6 million for the three and six months ended June 30, 2013, respectively, compared to the same periods in 2012 primarily due to less production from landfill gas fired electric production facilities compared to the prior year.

Discontinued Operations — The results are primarily comprised of environmental remediation and product liability litigation associated with previously disposed of businesses.

LIQUIDITY AND CAPITAL RESOURCES:

Liquidity needs are driven by factors that include natural gas commodity prices; the impact of weather on customer bills; lags in fully collecting gas costs from customers under the BGSS charge; working capital needs of our energy trading and marketing activities; the timing of construction and remediation expenditures and related permanent financings; the timing of equity contributions to unconsolidated affiliates; mandated tax payment dates; both discretionary and required repayments of long-term debt; and the amounts and timing of dividend payments.

Cash Flows from Operating Activities — Liquidity needs are first met with net cash provided by operating activities. Net cash provided by operating activities totaled $62.5 million and $56.2 million in the first six months of 2013 and 2012, respectively. Net cash provided by operating activities varies from year-to-year primarily due to the impact of weather on customer demand and related gas purchases, customer usage factors related to conservation efforts and the price of the natural gas commodity, inventory utilization, and gas cost recoveries.  Operating activities in the first six months of 2013 produced more net cash than the same period in 2012, primarily due to higher collections under utility regulatory clauses during the first six months of 2013 that were under-recovered in 2012 as a result of warmer than normal weather. The Company also made a smaller pension contribution in the first six months of 2013 as compared to the same period in 2012 as discussed on Note 9 to the condensed consolidated financial statements. The Company strives to keep its pension plans fully funded. When factors such as lesser than expected asset performance and/or declining discount rates negatively impact the funding status of the plans, the Company increases its contributions to supplant that funding shortfall. While discount rates continued to decline, greater than expected asset performance during 2012 added significantly to improving the Company's funding status, which resulted in a decrease in the pension contribution during 2013.

Cash Flows from Investing Activities — SJI has a continuing need for cash resources and capital, primarily to invest in new and replacement facilities and equipment. Net cash outflows for capital expenditures, which are primarily construction projects, for the first six months of 2013 and 2012 amounted to $88.3 million and $96.9 million, respectively. We estimate the net cash outflows for construction projects for fiscal years 2013, 2014 and 2015 at SJI to be approximately $325.9 million, $312.5 million and $230.2 million, respectively. The high level of capital expenditures is due to a combination of the accelerated infrastructure investment programs, a major pipeline project to support an electric generation facility, and a new customer information system, all at SJG.  For capital expenditures, including those under SJG’s CIRT and AIRP, the Company will use short-term borrowings under lines of credit from commercial banks and the commercial paper program to finance capital expenditures as incurred. From time to time, the Company will refinance the short-term debt incurred to support capital expenditures with long-term debt.

In support of its risk management activities, the Company is required to maintain margin accounts with selected counterparties as collateral for its forward contracts, swap agreements, options contracts and futures contracts. These margin accounts are included in Restricted Investments or Margin Account Liability, depending upon the value of the related contracts (the change in the Margin Account Liability is reflected in cash flows from Operating Activities) on the condensed consolidated balance sheets. The required amount of restricted investments changes on a daily basis due to fluctuations in the market value of the related outstanding contracts and are difficult to predict. Margin posted by the Company increased by $13.8 million in the first six months of 2013, compared with a decrease of $7.8 million in the same period of 2012.

During the six months ended June 30, 2013 and 2012, the Company made investments in, and provided net advances to unconsolidated affiliates of $7.3 million and $82.5 million, respectively. These amounts do not include the cash proceeds from LVE and the repayment of the advances to Energenic as discussed below. The purpose of these investments and advances was to cover certain project related costs of affiliates.

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In March 2013, substantially all of the assets of Marina's joint venture, LVE Energy Partners, LLC (LVE), an entity in which Marina has a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.6 million. See Note 11 to the condensed consolidated financial statements.

In April 2012, Energenic acquired The Energy Network, LLC, a holding company for the Hartford Steam Company, TEN Companies and CNE Power I, LLC. In conjunction with this acquisition, Marina provided $35.4 million of advances to Energenic, which was repaid by Energenic during the second quarter of 2013 as permanent financing was obtained.

Cash Flows from Financing Activities — Short-term borrowings from the commercial paper program and lines of credit from commercial banks are used to supplement cash flows from operations, to support working capital needs and to finance capital expenditures as incurred. From time to time, short-term debt incurred to finance capital expenditures is refinanced with long-term debt.

Credit facilities and available liquidity as of June 30, 2013 were as follows (in thousands):

Company	Total Facility		Usage		Available Liquidity		Expiration Date
SJG:
Commercial Paper Program/Revolving Credit Facility	$	200,000	$	93,000	$	107,000	May 2015
Uncommitted Bank Lines (B)	10,000		—		10,000		August 2013
Total SJG	$	210,000	$	93,000	$	117,000
SJI:
Revolving Credit Facility	$	400,000	$	180,300	$	219,700	February 2018 (A)
Term Line of Credit	50,000		50,000		—		November 2013
Total SJI	450,000		230,300		219,700
Total	$	660,000	$	323,300	$	336,700

(A) Includes letters of credit outstanding in the amount of $27.6 million.

(B) Although there can be no assurances, SJG anticipates renewing the remaining line of credit during the third quarter 2013.

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. All committed facilities contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements), measured on a quarterly basis. SJI and SJG were in compliance with these covenants as of June 30, 2013. Borrowings under these credit facilities are at market rates. The weighted average borrowing cost, which changes daily, was 0.98% and 0.95% at June 30, 2013 and 2012, respectively.  Based upon the existing credit facilities and a regular dialogue with our banks, we believe there will continue to be sufficient credit available to meet our business’ future liquidity needs.

SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million.  The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes.  SJG uses the commercial paper program in tandem with the $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.

SJI supplements its operating cash flow, commercial paper program and credit lines with both debt and equity capital. Over the years, SJG has used long-term debt, primarily in the form of First Mortgage Bonds and Medium Term Notes, secured by the same pool of utility assets, to finance its long-term borrowing needs. These needs are primarily capital expenditures for property, plant and equipment. 

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SJI raises equity capital through its Dividend Reinvestment Plan (DRP). Participants in SJI's DRP receive newly-issued shares. Prior to April 2013, shares of common stock offered by the DRP were issued at a 2% discount directly by SJI from its authorized but unissued shares of common stock. In April 2013, SJI discontinued the 2% discount on shares issued through the DRP in an effort to manage the amount of equity raised through the plan. SJI raised $12.5 million and $9.3 million of equity capital through the DRP during the six months ended June 30, 2013 and 2012, respectively.

SJI’s capital structure was as follows:

	As of June 30, 2013		As of December 31, 2012
Equity	45.5	%	43.3	%
Long-Term Debt	37.0		36.8
Short-Term Debt	17.5		19.9
Total	100.0	%	100.0	%

SJI has paid dividends on its common stock for 62 consecutive years and has increased that dividend each year for the last thirteen years.  The Company currently looks to grow that dividend by at least 6% to 7% per year and has a targeted payout ratio of between 50% and 60% of Economic Earnings.  In setting the dividend rate, the Board of Directors of SJI considers future earnings expectations, payout ratio, and dividend yield relative to those at peer companies, as well as returns available on other income-oriented investments.  However, there can be no assurance that the Company will be able to continue to increase the dividend, meet the targeted payout ratio or pay a dividend at all in the future.

COMMITMENTS AND CONTINGENCIES:

SJI has a continuing need for cash resources and capital, primarily to invest in new and replacement facilities and equipment, and for environmental remediation costs. Cash outflows for capital expenditures for the first six months of 2013 and 2012 amounted to $88.3 million and $96.9 million, respectively. Management estimates the net cash outflows for construction projects for 2013, 2014 and 2015 at SJI to be approximately $325.9 million, $312.5 million and $230.2 million, respectively. The high level of capital expenditures is due to a combination of the accelerated infrastructure investment programs, a major pipeline project to support an electric generation facility, and a new customer information system, all at SJG. Costs for remediation projects, net of insurance reimbursements, for the first six months of 2013 and 2012 amounted to net cash inflows of $2.3 million and $2.1 million, respectively. Total net cash outflows for remediation projects are expected to be $12.1 million, $25.2 million and $25.8 million for 2013, 2014 and 2015, respectively.  As discussed in Notes 10 and 15 to the Consolidated Financial Statements in Item 8 of SJI’s 10-K as of December 31, 2012, certain environmental costs are subject to recovery from insurance carriers and ratepayers.

As of June 30, 2013, SJI provided $27.6 million of standby letters of credit through SJI’s revolving credit facility to enable SJE to market retail electricity and for various construction activities. The Company 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.

Contractual Obligations - There were no significant changes to the Company’s contractual obligations described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012, except for construction obligations which increased approximately $74.8 million in total since December 31, 2012 due to additional agreements on solar projects at Marina, and commodity supply purchase obligations which decreased approximately $5.0 million in total since December 31, 2012 due to payments made during the first six months of 2013 on commitments at SJE and SJRG.

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Off-Balance Sheet Arrangements – An off-balance sheet arrangement is any contractual arrangement involving an unconsolidated entity under which the company has either made guarantees, or has certain other interests or obligations.

The Company has recorded a liability of $0.3 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, 2013 for the fair value of the following guarantees:

• In April 2007, SJI guaranteed certain obligations of LVE Energy Partners, LLC (LVE), an unconsolidated joint venture in which Marina has a 50% equity interest.  LVE entered into a 25-year contract with a resort developer to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.  LVE began construction of the facility in 2007 and expected to provide full energy service in 2010 when the resort was originally scheduled to be completed.  LVE suspended construction of the district energy system and central energy center in January 2009 after the resort developer’s announcement that it was delaying the completion of construction of the resort.

In March 2013, the resort developer purchased substantially all of the assets of LVE. As a result, the guarantees provided by SJI of certain performance obligations of LVE under the operating agreements between LVE and the resort developer were canceled.

During the six months ended June 30, 2013 the Company received $57.6 million of repayments of advances from LVE. As of June 30, 2013, the Company had remaining unsecured Notes Receivable - Affiliate of approximately $7.0 million due from LVE on the condensed consolidated balance sheets related to this project. During 2013, SJI provided support to LVE of approximately $1.8 million to cover interest and other project related costs.

As a result of the sale of substantially all of the assets, management has evaluated the investment in LVE and concluded that the fair value of this investment continues to be in excess of the carrying value as of June 30, 2013

SJI and its joint venture partner have guaranteed the repayment of interest rate derivative contracts held by LVE which mature in November 2013. As of June 30, 2013 the amount required to satisfy these contracts is approximately $3.2 million. LVE is expected to have sufficient resources to satisfy these interest rate derivative contracts upon the liquidation of its remaining assets. 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 this guarantee.

• 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 February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 20 year contract with a developer to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012 and as a result, ACR is providing full energy services to the complex. Marina and its joint venture partner have agreed to provide a $5.0 million letter of credit to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI to or on behalf of ACR.

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• In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, of 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 is expected to be completed during the second half of 2013. Marina and its joint venture partner are obligated to make capital contributions to UMM, through Energenic, totaling approximately $10.0 million. In addition, SJI has guaranteed certain obligations of UMM under the operating and lease agreements between UMM and the university, for the terms of the agreements, commencing with the first year of operations. SJI has guaranteed up to $2.2 million for the first year. This amount is adjusted each year based upon the Consumer Price Index. SJI has also guaranteed certain construction obligations of UMM during the construction period, the majority of which are supported by a surety bond. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.

• As of June 30, 2013, SJI had issued $5.1 million of guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.

Pending Litigation— The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.2 million related to all claims in the aggregate as of both June 30, 2013 and December 31, 2012. 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.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity Market Risks — Certain regulated and non-regulated 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 other third parties. These subsidiaries are subject to market risk due to price fluctuations. To hedge against this risk, we enter into a variety of physical and financial transactions including forward contracts, swaps, futures and options agreements. To manage these transactions, SJI has a well-defined risk management policy approved by our Board of Directors that includes volumetric and monetary limits. Management reviews reports detailing activity daily. Generally, the derivative activities described above are entered into for risk management purposes.

SJG and SJE transact commodities on a physical basis and typically do not enter into financial derivative positions directly. SJRG manages risk in the natural gas markets for these entities as well as for its own portfolio by entering into the types of transactions noted above. As part of its gas purchasing strategy, SJG uses financial contracts through SJRG to hedge against forward price risk. These contracts are recoverable through SJG’s BGSS, subject to BPU approval. It is management’s policy, to the extent practical, within predetermined risk management policy guidelines, to have limited unmatched positions on a deal or portfolio basis while conducting these activities. As a result of holding open positions to a minimal level, the economic impact of changes in value of a particular transaction is substantially offset by an opposite change in the related hedge transaction.

SJI has entered into certain contracts to buy, sell, and transport natural gas and to buy and sell retail electricity. SJI recorded a net unrealized pre-tax (loss) gain of $(16.7) million and $3.3 million in earnings during the three months ended June 30, 2013 and 2012, respectively, and a net unrealized pre-tax (loss) gain of $(23.8) and $10.3 during the six months ended June 30, 2013 and 2012, respectively, which are included with realized gains and losses in Operating Revenues — Nonutility.  

The fair value and maturity of these energy-related contracts determined under the mark-to-market method as of June 30, 2013 is as follows (in thousands):

Assets
Source of Fair Value	Maturity  < 1 Year		Maturity  1 -3 Years		Maturity Beyond 3 Years		Total
Prices actively quoted	$	5,562	$	878	$	4	$	6,444
Prices provided by other external sources	11,839		5,636		336		17,811
Prices based on internal models or other valuable methods	16,425		6,969		819		24,213
Total	$	33,826	$	13,483	$	1,159	$	48,468
Liabilities
Source of Fair Value	Maturity  <1 Year		Maturity 1 -3 Years		Maturity Beyond 3Years		Total
Prices actively quoted	$	3,095	$	960	$	10	$	4,065
Prices provided by other external sources	17,296		9,331		122		26,749
Prices based on internal models or other valuable methods	17,588		11,100		4,040		32,728
Total	$	37,979	$	21,391	$	4,172	$	63,542

NYMEX (New York Mercantile Exchange) is the primary national commodities exchange on which natural gas is traded. Basis represents the price of a NYMEX natural gas futures contract adjusted for the difference in price for delivering the gas at another location. Contracted volumes of our NYMEX contracts included in the table above are 6.5 million dekatherms (dts) with a weighted-average settlement price of $4.02 per dt.  Contracted volumes of our basis contracts included in the table above are 27.0 million dts with a weighted average settlement price of $0.02 per dt. Contracted volumes of our discounted index related purchase and sales contracts included in the table above are 104.4 million dts with a weighted average price of $(0.04) per dt.  Contracted volumes of electric included in the table above are less than 0.1 million mwh with a weighted average settlement price of $48.27 per mwh.

48

A reconciliation of SJI’s estimated net fair value of energy-related derivatives follows (in thousands):

Net Derivatives — Energy Related Assets,  January 1, 2013	$	7,308
Contracts Settled During Six Months Ended June 30, 2013, Net	(33		)
Other Changes in Fair Value from Continuing and New Contracts, Net	(22,349		)
Net Derivatives — Energy Related Liabilities June 30, 2013	$	(15,074	)

Interest Rate Risk— Our exposure to interest-rate risk relates primarily to short-term, variable-rate borrowings. Short-term, variable-rate debt outstanding at June 30, 2013 was $295.7 million and averaged $275.3 million during the first six months of 2013. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $1.7 million increase in our annual interest expense, net of tax. The 100 basis point increase was chosen for illustrative purposes, as it provides a simple basis for calculating the impact of interest rate changes under a variety of interest rate scenarios. Over the past five years, the change in basis points (b.p.) of our average monthly interest rates from the beginning to end of each year was as follows: 2012 - 9 b.p. decrease; 2011 - 33 b.p. increase; 2010 – 13 b.p. decrease; 2009 – 29 b.p. decrease; and 2008 – 397 b.p. decrease.  At June 30, 2013, our average interest rate on variable-rate debt was 1.02%.

We issue long-term debt either at fixed rates or use interest rate derivatives to limit our exposure to changes in interest rates on variable-rate, long-term debt. As of June 30, 2013, the interest costs on all but $27.1 million of our long-term debt was either at a fixed-rate or hedged via an interest rate derivative. Consequently, interest expense on existing long-term debt is not significantly impacted by changes in market interest rates.

As of June 30, 2013, SJI’s active interest rate swaps were as follows:

Amount		Fixed Interest Rate	Start Date	Maturity	Type	Obligor
$	3,900,000	4.795%	12/1/2004	12/1/2014	Taxable	Marina
$	8,000,000	4.775%	11/12/2004	11/12/2014	Taxable	Marina
$	14,500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	500,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	330,000	3.905%	3/17/2006	1/15/2026	Tax-exempt	Marina
$	7,100,000	4.895%	2/1/2006	2/1/2016	Taxable	Marina
$	12,500,000	3.430%	12/1/2006	2/1/2036	Tax-exempt	SJG
$	12,500,000	3.430%	12/1/2006	2/1/2036	Tax-exempt	SJG

Credit Risk - As of June 30, 2013, approximately $14.9 million, or 30.7%, of the current and noncurrent Derivatives – Energy Related Assets are with two retail counterparties. One of these counterparties has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assignable to SJI in the event of a default by the counterparty.

As of June 30, 2013, SJRG had $119.9 million of Accounts Receivable under sales contracts. Of that total, 87.9% were with regulated utilities or companies rated investment-grade or guaranteed by an investment-grade-rated parent or were with companies where we have a collateral arrangement or insurance coverage. The remainder of the Accounts Receivable were within approved credit limits.

49

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

The Company’s management, with the participation of its chief executive officer and chief financial officer, evaluated the effectiveness of the design and operation of the Company’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of June 30, 2013. Based on that evaluation, the Company’s chief executive officer and chief financial officer concluded that the disclosure controls and procedures employed at the Company are effective.

Changes in Internal Control Over Financial Reporting

There has not been any change in the Company’s internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act, during the fiscal quarter ended June 30, 2013 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

50

PART II — OTHER INFORMATION

Item l. Legal Proceedings

Information required by this Item is incorporated by reference to Part I, Item 2, Pending Litigation, beginning on page 47.

Item 1A. Risk Factors

The following paragraph should be read in conjunction with the risk factors included in Part I, Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.

Failures in the security of our computer systems through cyberattacks, hackers or other sources, could have a material adverse impact on our business and results of operations.  SJI uses computer systems and services that involve the storage of confidential information on our employees, customers and vendors. In addition, certain computer systems monitor and control our generation and distribution processes.   Experienced hackers may be able to develop and deploy viruses that exploit the security of our computer systems and thus obtain confidential information and/or disrupt significant business processes.  Unauthorized access to confidential information or disruptions to significant business processes could damage our reputation and negatively impact our results of operations and financial condition.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Items 2(a) and 2(b) are not applicable.

(c) Issuer Purchases of Equity Securities - There were no purchases by SJI of its own common stock during the six months ended June 30, 2013.

Item 6. Exhibits

(a)  Exhibits

Exhibit No.	Description
31.1	Certification of Chief Executive Officer Pursuant to Rule 13a-14(a) of the Exchange Act.
31.2	Certification of Chief Financial Officer Pursuant to Rule 13a-14(a) of the Exchange Act.
32.1	Certification of Chief Executive Officer Pursuant to Rule 13a-14(b) of the Exchange Act as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code).
32.2	Certification of Chief Financial Officer Pursuant to Rule 13a-14(b) of the Exchange Act as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code).
101	The following financial statements from South Jersey Industries’ Quarterly Report on Form 10-Q for the three months ended June 30, 2013, filed with the Securities and Exchange Commission on August 8, 2013, formatted in XBRL (eXtensible Business Reporting Language): (i) the Condensed Consolidated Statements of Income; (ii) the Condensed Consolidated Statements of Comprehensive Income; (iii) the Condensed Consolidated Statements of Cash Flows; (iv) the Condensed Consolidated Balance Sheets and (v) the Notes to Condensed Consolidated Financial Statements.

51

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized

		SOUTH JERSEY INDUSTRIES, INC.
		(Registrant)
Dated:	August 8, 2013	By:	/s/ Edward J. Graham
			Edward J. Graham
			Chairman, President & Chief Executive Officer
Dated:	August 8, 2013	By:	/s/ David A. Kindlick
			David A. Kindlick
			Senior Vice President & Chief Financial Officer

52

EX-31.1

Exhibit 31.1

CERTIFICATION

I, Edward J. Graham, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the period ended June 30, 2013, of South Jersey Industries, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15 d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent function):

a) all significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

		South Jersey Industries, Inc.
Date:	August 8, 2013	By:	/s/ Edward J. Graham
			Edward J. Graham
			Chairman, President & Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION

I, David A. Kindlick, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the period ended June 30, 2013, of South Jersey Industries, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15 d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent function):

a) all significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

		South Jersey Industries, Inc.
Date:	August 8, 2013	By:	/s/ David A. Kindlick
			David A. Kindlick
			Senior Vice President & Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906 OF

THE SARBANES-OXLEY ACT OF 2002

In connection with the filing of the Quarterly Report on Form 10-Q of South Jersey Industries, Inc. (the “Company”) for the period ended June 30, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Edward J. Graham, Chief Executive Officer of the Company, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or Section 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Edward J. Graham

Name:  Edward J. Graham

Title:  Chief Executive Officer

August 8, 2013

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906 OF

THE SARBANES-OXLEY ACT OF 2002

In connection with the filing of the Quarterly Report on Form 10-Q of South Jersey Industries, Inc. (the “Company”) for the period ended June 30, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, David A. Kindlick, Chief Financial Officer of the Company, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or Section 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ David A. Kindlick

Name:  David A. Kindlick

Title:  Chief Financial Officer

August 8, 2013

XML

DERIVATIVE INSTRUMENTS

6 Months Ended

Jun. 30, 2013

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, 2013, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 17.8 MMdts (1 MMdts = one million decatherms) of expected future purchases of natural gas, 24.2 MMdts of expected future sales of natural gas, 1.3 MMmwh (1 MMmwh = one million megawatt hours) of expected future purchases of electricity and 1.2 MMmwh of expected future sales of electricity. In addition to these derivative contracts, the Company had basis and index related purchase and sales contracts totaling 77.4 MMdts.  The value of these contracts are not significant as of June 30, 2013. 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 on the condensed 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 other significant changes to the Company’s active interest rate swaps since December 31, 2012 which are described in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012.

The fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of June 30, 2013 and December 31, 2012, are as follows (in thousands):

Derivatives not designated as hedging instruments under GAAP	June 30, 2013				December 31, 2012
	Assets		Liabilities		Assets		Liabilities
Energy related commodity contracts:
Derivatives – Energy Related – Current	$	33,826	$	37,979	$	24,242	$	23,828
Derivatives – Energy Related – Non-Current	14,642		25,563		12,297		5,403
Interest rate contracts:
Derivatives - Other - Non-Current	—		9,091		—		13,462
Total derivatives not designated as hedging instruments under GAAP	48,468		72,633		36,539		42,693
Total Derivatives	$	48,468	$	72,633	$	36,539	$	42,693

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, 2013 and December 31, 2012, information related to these offsetting arrangements were as follows (in thousands):

As of June 30, 2013
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	48,468		$	—	$	48,468		$	(10,162	)	(A)	$	—	$	38,306
Derivatives - Energy Related Liabilities	$	(63,542	)	$	—	$	(63,542	)	$	10,162		(B)	$	24,078	$	(29,302	)
Derivatives - Other	$	(9,091	)	$	—	$	(9,091	)	$	—			$	—	$	(9,091	)

As of December 31, 2012
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	$	36,539		$	—	$	36,539		$	(12,975	)	(A)	$	—	$	23,564
Derivatives - Energy Related Liabilities	$	(29,231	)	$	—	$	(29,231	)	$	12,975		(B)	$	6,347	$	(9,909	)
Derivatives - Other	$	(13,462	)	$	—	$	(13,462	)	$	—			$	—	$	(13,462	)

(A) The balances at June 30, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at June 30, 2013 and December 31, 2012 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, 2013 and 2012 are as follows (in thousands):

	Three Months Ended June 30,						Six Months Ended June 30,
Derivatives in Cash Flow Hedging Relationships	2013			2012			2013			2012
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$	—		$	(888	)	$	—		$	(752	)
Losses reclassified from AOCL into income (a)	$	(112	)	$	(183	)	$	(224	)	$	(370	)
Gains (losses) recognized in income on ineffective portion (a)	—			—			—			—

(a) Included in Interest Charges

	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments under GAAP	2013			2012		2013			2012
(Losses) gains on energy related commodity contracts (a)	$	(16,722	)	$	3,308	$	(23,771	)	$	10,279
Gains on interest rate contracts (b)	1,250			84		1,775			220
Total	$	(15,472	)	$	3,392	$	(21,996	)	$	10,499

(a)  Included in Operating Revenues - Non Utility

(b)  Included in Interest Charges

Net realized gains of $1.3 million and losses of$5.7 million for the three months ended June 30, 2013 and 2012, respectively, and losses of $0.2 million and $10.7 million for the six months ended June 30, 2013 and 2012, respectively, associated with SJG’s energy-related financial commodity contracts are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy related financial commodity contracts are deferred in Regulatory Assets or Liabilities and there is no impact to earnings.

Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on June 30, 2013, is $29.5 million.   If the credit-risk-related contingent features underlying these agreements were triggered on June 30, 2013, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $25.1 million after offsetting asset positions with the same counterparties under master netting arrangements.

XML

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES, LEVEL THREE INPUTS (Details) (Forward Contracts [Member], Fair Value, Inputs, Level 3 [Member], USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Natural Gas [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	$ 17,019	$ 4,340
Liabilities	28,069	4,986
Electricity [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	7,194	6,590
Liabilities	$ 4,659	$ 3,182
Minimum [Member] | Natural Gas [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	(1.20)	(0.35)
Maximum [Member] | Natural Gas [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	3.58	2.92
Weighted Average [Member] | Natural Gas [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	(0.49)	(0.12)
On-Peak [Member] | Minimum [Member] | Electricity [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	19.72%	21.62%
On-Peak [Member] | Maximum [Member] | Electricity [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	100.00%	100.00%
On-Peak [Member] | Weighted Average [Member] | Electricity [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	60.44%	53.64%
Off-Peak [Member] | Minimum [Member] | Electricity [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	0.00%	0.00%
Off-Peak [Member] | Maximum [Member] | Electricity [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	80.28%	78.38%
Off-Peak [Member] | Weighted Average [Member] | Electricity [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Fixed electric load profile	39.56%	46.36%

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Statement of Cash Flows [Abstract]
Net Cash Provided by Operating Activities	$ 62,509	$ 56,213
Cash Flows from Investing Activities:
Capital Expenditures	(88,305)	(96,891)
Net (Purchase of) Proceeds from Sale of Restricted Investments in Margin Account	(13,840)	7,775
Purchase of Restricted Investments with Escrowed Loan Proceeds	(40)	0
Investment in Long-Term Receivables	(3,256)	(2,871)
Proceeds from Long-Term Receivables	3,433	3,781
Purchase of Company Owned Life Insurance	(3,785)	(3,525)
Investment in Affiliate	(2,492)	(28,979)
Advances on Notes Receivable - Affiliate	(6,157)	(58,178)
Repayment of Notes Receivable - Affiliate	94,360	4,681
Other	0	(584)
Net Cash Used in Investing Activities	(20,082)	(174,791)
Cash Flows from Financing Activities:
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(43,200)	1,900
Proceeds from Issuance of Long-Term Debt	0	150,000
Principal Repayments of Long-Term Debt	0	(35,000)
Payments for Issuance of Long-Term Debt	(5)	(583)
Premium for Early Retirement of Debt	0	(700)
Dividends on Common Stock	(14,102)	(12,200)
Proceeds from Sale of Common Stock	12,502	9,256
Net Cash (Used in) Provided by Financing Activities	(44,805)	112,673
Net Decrease in Cash and Cash Equivalents	(2,378)	(5,905)
Cash and Cash Equivalents at Beginning of Period	4,638	7,538
Cash and Cash Equivalents at End of Period	$ 2,260	$ 1,633

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FINANCIAL INSTRUMENTS

6 Months Ended

Jun. 30, 2013

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, 2013 and December 31, 2012, the escrowed proceeds, including interest earned, totaled $1.4 million and $1.3 million, respectively.

The Company maintains margin accounts with selected counterparties to support its risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy related contracts with the respective counterparties decrease. As of June 30, 2013 and December 31, 2012, the balances in these accounts totaled $30.4 million and $16.6 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at June 30, 2013 and December 31, 2012, which would be included in Level 1 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities).

LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources.  The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest.  The carrying amounts of such loans were $13.8 million and $13.6 million as of June 30, 2013 and December 31, 2012, respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the condensed consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.3 million as of both June 30, 2013 and December 31, 2012.  The annual amortization to interest is not material to the Company’s condensed consolidated financial statements.  The carrying amounts of these receivables approximate their fair value at June 30, 2013 and December 31, 2012, 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, 2013, approximately $14.9 million, or 30.7%, of the current and noncurrent Derivatives – Energy Related Assets are with two retail counterparties. One of these counterparties 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 a 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 $23.6 million as of both June 30, 2013 and December 31, 2012, respectively. 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 $21.1 million and $21.6 million, net of amortization, within Finance Obligation on the condensed consolidated balance sheets at June 30, 2013 and December 31, 2012, 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, 2013 and December 31, 2012, 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, 2013 and December 31, 2012, were $649.7 million and $682.3 million, respectively.  The carrying amounts of SJI's long-term debt, including current maturities, as of both June 30, 2013 and December 31, 2012, was $626.4 million.

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DISCONTINUED OPERATIONS AND AFFILIATIONS (Tables)

6 Months Ended

Jun. 30, 2013

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, were (in thousands, except per share amounts):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Loss Before Income Taxes:
Sand Mining	$	(20	)	$	(705	)	$	(92	)	$	(901	)
Fuel Oil	(23		)	(61		)	(675		)	(75		)
Income Tax Benefits	15			268			268			342
Loss from Discontinued Operations — Net	$	(28	)	$	(498	)	$	(499	)	$	(634	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic	$	(0.001	)	$	(0.016	)	$	(0.015	)	$	(0.021	)
Diluted	$	(0.001	)	$	(0.016	)	$	(0.016	)	$	(0.021	)

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ACCUMULATED OTHER COMPREHENSIVE LOSS 2 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended			6 Months Ended
	Jun. 30, 2013		Jun. 30, 2012	Jun. 30, 2013		Jun. 30, 2012
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	$ (3,420)		$ (5,195)	$ (8,128)		$ (10,688)
Other Income	2,665		3,658	6,534		5,531
Equity in Loss of Affiliated Companies	632		1,040	601		1,247
Income Tax Benefit (Expense)	11,632		1,072	3,860		(14,812)
Income from Continuing Operations	916		10,832	44,253		65,043
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Income from Continuing Operations	88			4,679
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Gain (Loss) on Derivatives-Other [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	112			224
Income Tax Benefit (Expense)	(46)	[1]		(92)	[1]
Income from Continuing Operations	66			132
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Gain (Loss) on Available-for-Sale Securities [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Other Income	0			(827)
Income Tax Benefit (Expense)	0	[1]		338	[1]
Income from Continuing Operations	0			(489)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Other Comprehensive Income (Loss) of Affiliated Companies [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Equity in Loss of Affiliated Companies	35			8,511
Income Tax Benefit (Expense)	(13)	[1]		(3,475)	[1]
Income from Continuing Operations	$ 22			$ 5,036

[1] Determined using a combined statutory tax rate of 41%.

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES

6 Months Ended

Jun. 30, 2013

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, 2013	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,859	$	7,859	$	—	$	—
Derivatives – Energy Related Assets (B)	48,468		6,444		17,811		24,213
	$	56,327	$	14,303	$	17,811	$	24,213
Liabilities
Derivatives – Energy Related Liabilities (B)	$	63,542	$	4,065	$	26,749	$	32,728
Derivatives – Other (C)	9,091		—		9,091		—
	$	72,633	$	4,065	$	35,840	$	32,728

As of December 31, 2012	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,538	$	787	$	6,751	$	—
Derivatives – Energy Related Assets (B)	36,539		9,404		16,205		10,930
	$	44,077	$	10,191	$	22,956	$	10,930
Liabilities
Derivatives – Energy Related Liabilities (B)	$	29,231	$	5,399	$	15,664	$	8,168
Derivatives – Other (C)	13,462		—		13,462		—
	$	42,693	$	5,399	$	29,126	$	8,168

(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 are 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 are 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, 2013		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$17,019	$28,069	Discounted Cash Flow	Forward price (per dt)	$(1.20) - $3.58 [$(0.49)]
Forward Contract - Electric	$7,194	$4,659	Discounted Cash Flow	Fixed electric load profile (on-peak)	19.72% - 100.00% [60.44%]
				Fixed electric load profile (off-peak)	0.00% - 80.28% [39.56%]

Type	Fair Value at December 31, 2012				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	4,340	$	4,986	Discounted Cash Flow	Forward price (per dt)	$(0.35) - $2.92 [$(0.12)]
Forward Contract - Electric	$	6,590	$	3,182	Discounted Cash Flow	Fixed electric load profile (on-peak)	21.62% - 100.00% [53.64%]
						Fixed electric load profile (off-peak)	0.00% - 78.38% [46.36%]

The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and six months ended June 30, 2013 and 2012, using significant unobservable inputs (Level 3), are as follows (in thousands):

	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
Balance at beginning of period	$	1,627		$	2,762
Total losses realized/unrealized included in earnings	(12,022		)	(12,723		)
Transfers in/(out) of Level 3 (A)	928			928
Settlements	952			518
Balance at June 30	$	(8,515	)	$	(8,515	)

(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, 2013, $0.9 million of net derivatives assets were transferred from Level 2 to Level 3, due to decreased observability of market data. The transfer was recognized as of the end of the second quarter.

	Three Months Ended June 30, 2012			Six Months Ended June 30, 2012
Balance at beginning of period	(1,958		)	(5,958		)
Total losses realized/unrealized included in earnings	3,306			3,475
Settlements	1,730			5,561
Balance at June 30	$	3,078		$	3,078

Total losses for 2013 included in earnings that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of June 30, 2013, is $(12.0) million.  These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

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DERIVATIVE INSTRUMENTS (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 48,468	$ 36,539
Derivative Liability, Fair Value, Gross Asset	$ 72,633	$ 42,693
Basis and Index Related Purchase and Sales Contracts [Member]
Derivative [Line Items]
Outstanding derivative contracts notional amount	77.4
Natural Gas (in MMdts) [Member] | Derivative Transaction Type, Purchase [Member]
Derivative [Line Items]
Outstanding derivative contracts notional amount	17.8
Natural Gas (in MMdts) [Member] | Derivative Transaction Type, Sale [Member]
Derivative [Line Items]
Outstanding derivative contracts notional amount	24.2
Electricity (in mwh) [Member] | Derivative Transaction Type, Purchase [Member]
Derivative [Line Items]
Outstanding derivative contracts notional amount	1,300,000.0
Electricity (in mwh) [Member] | Derivative Transaction Type, Sale [Member]
Derivative [Line Items]
Outstanding derivative contracts notional amount	1,200,000.0

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SUBSEQUENT EVENT (Details) (USD $)		1 Months Ended
	Jun. 30, 2013	Jul. 31, 2013 Subsequent Event [Member] South Jersey Gas Company [Member] Mortgages [Member] Series Due 2013, 4.46 Percent [Member]
Subsequent Event [Line Items]
Debt redeemed at par		$ 10,500,000
Stated interest rate	7.50%	4.46%

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FINANCIAL INSTRUMENTS (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted investments held In escrow	$ 1.4	$ 1.3
Margin accounts with selected counterparties to support risk management activities	30.4	16.6
South Jersey Gas Company [Member] | Financing Receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Long-term receivables, net of unamortized discount	13.8	13.6
Imputed interest on long term receivables	$ 1.3	$ 1.3

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REGULATORY ASSETS & REGULATORY LIABILITIES (Tables)

6 Months Ended

Jun. 30, 2013

Regulatory Assets and Liabilities Disclosure [Abstract]

Schedule of Regulatory Assets

Regulatory Assets consisted of the following items (in thousands):

	June 30, 2013		December 31, 2012
Environmental Remediation Costs:
Expended - Net	$	30,387	$	37,892
Liability for Future Expenditures	110,148		107,410
Deferred Asset Retirement Obligation Costs	30,594		30,199
Deferred Pension and Other Postretirement Benefit Costs	95,897		95,897
Conservation Incentive Program Receivable	11,824		31,686
Societal Benefit Costs Receivable	12,502		12,801
Premium for Early Retirement of Debt	997		1,075
Deferred Interest Rate Contracts	5,164		7,761
Energy Efficiency Tracker	11,949		12,306
Pipeline Supplier Service Charges	7,938		8,771
Other Regulatory Assets	9,006		6,858
Total Regulatory Assets	$	326,406	$	352,656

Schedule of Regulatory Liabilities

Regulatory Liabilities consisted of the following items (in thousands):

	June 30, 2013		December 31, 2012
Excess Plant Removal Costs	$	42,673	$	45,593
Deferred Revenues - Net	14,693		10,924
Other Regulatory Liabilities	3,249		—
Total Regulatory Liabilities	$	60,615	$	56,517

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SEGMENTS OF BUSINESS (Tables)

6 Months Ended

Jun. 30, 2013

Segment Reporting [Abstract]

Segments of Business

Information about SJI’s operations in different reportable operating segments is presented below (in thousands):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Operating Revenues:
Gas Utility Operations	$	66,536		$	59,177		$	240,634		$	238,613
Wholesale Energy Operations	(10,699		)	(471		)	(4,482		)	17,171
Retail Energy Operations:
Retail Gas and Other Operations	24,585			13,600			58,698			31,792
Retail Electric Operations	31,419			38,365			62,148			88,552
On-Site Energy Production	9,965			9,356			19,059			17,257
Appliance Service Operations	3,133			3,578			6,441			6,860
Subtotal Retail Energy Operations	69,102			64,899			146,346			144,461
Corporate & Services	7,362			6,331			15,842			13,045
Subtotal	132,301			129,936			398,340			413,290
Intersegment Sales	(9,709		)	(8,023		)	(20,118		)	(16,545		)
Total Operating Revenues	$	122,592		$	121,913		$	378,222		$	396,745

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Operating Income:
Gas Utility Operations	$	8,069		$	7,465		$	65,864		$	66,320
Wholesale Energy Operations	(19,200		)	(2,843		)	(24,357		)	7,829
Retail Energy Operations:
Retail Gas and Other Operations	(160		)	(395		)	(132		)	(547		)
Retail Electric Operations	(337		)	5,110			127			10,054
On-Site Energy Production	268			684			(905		)	346
Appliance Service Operations	799			222			785			(219		)
Subtotal Retail Energy Operations	570			5,621			(125		)	9,634
Corporate and Services	(32		)	14			4			(18		)
Total Operating (Loss) Income	$	(10,593	)	$	10,257		$	41,386		$	83,765
Depreciation and Amortization:
Gas Utility Operations	$	12,929		$	11,130		$	23,953		$	22,092
Wholesale Energy Operations	55			64			106			117
Retail Energy Operations:
Retail Gas and Other Operations	21			23			43			31
On-Site Energy Production	3,958			2,722			6,970			4,726
Appliance Service Operations	72			78			146			162
Subtotal Retail Energy Operations	4,051			2,823			7,159			4,919
Corporate and Services	221			171			446			335
Total Depreciation and Amortization	$	17,256		$	14,188		$	31,664		$	27,463
Interest Charges:
Gas Utility Operations	$	2,789		$	3,771		$	5,750		$	7,960
Wholesale Energy Operations	33			72			85			158
Retail Energy Operations:
Retail Gas and Other Operations	67			13			143			51
On-Site Energy Production	307			1,215			1,710			2,234
Subtotal Retail Energy Operations	374			1,228			1,853			2,285
Corporate and Services	1,212			837			2,720			1,558
Subtotal	4,408			5,908			10,408			11,961
Intersegment Borrowings	(988		)	(713		)	(2,280		)	(1,273		)
Total Interest Charges	$	3,420		$	5,195		$	8,128		$	10,688
Income Taxes:
Gas Utility Operations	$	2,269		$	1,887		$	23,040		$	22,864
Wholesale Energy Operations	(7,710		)	(1,028		)	(9,691		)	2,953
Retail Energy Operations:
Retail Gas and Other Operations	(52		)	(90		)	220			94
Retail Electric Operations	(139		)	2,087			51			4,107
On-Site Energy Production	(6,466		)	(4,056		)	(18,030		)	(15,230		)
Appliance Service Operations	338			109			342			(54		)
Subtotal Retail Energy Operations	(6,319		)	(1,950		)	(17,417		)	(11,083		)
Corporate and Services	128			19			208			78
Total Income Tax (Benefit) Expense	$	(11,632	)	$	(1,072	)	$	(3,860	)	$	14,812

	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
Property Additions:
Gas Utility Operations	$	44,764	$	40,220	$	81,806	$	80,876
Wholesale Energy Operations	25		8		34		12
Retail Energy Operations:
Retail Gas and Other Operations	35		50		37		103
On-Site Energy Production	14,949		5,705		17,526		11,002
Appliance Service Operations	—		2		—		2
Subtotal Retail Energy Operations	14,984		5,757		17,563		11,107
Corporate and Services	1,126		1,254		1,864		1,659
Total Property Additions	$	60,899	$	47,239	$	101,267	$	93,654

	June 30, 2013			December 31, 2012
Identifiable Assets (See Note 1):
Gas Utility Operations	$	1,834,645		$	1,786,459
Wholesale Energy Operations	250,792			204,358
Retail Energy Operations:
Retail Gas and Other Operations	32,152			39,481
Retail Electric Operations	28,528			21,919
On-Site Energy Production	472,603			543,416
Appliance Service Operations	2,748			3,244
Subtotal Retail Energy Operations	536,031			608,060
Discontinued Operations	1,886			78
Corporate and Services	295,085			337,010
Intersegment Assets	(263,942		)	(304,525		)
Total Identifiable Assets	$	2,654,497		$	2,631,440

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UNUSED LINES OF CREDIT (Details) (USD $)	6 Months Ended
	Jun. 30, 2013		Jun. 30, 2012
Line of Credit Facility [Line Items]
Total facility	$ 660,000,000
Usage	323,300,000
Available liquidity	336,700,000
Letters of credit outstanding	27,600,000
Weighted average borrowing cost	0.98%		0.95%
Average borrowings outstanding during the period	275,300,000		376,200,000
Maximum amounts outstanding during the period	369,500,000		462,200,000
Financial covenant, ratio of indebtedness to consolidated total capitalization	0.65 to 1
Minimum [Member]
Line of Credit Facility [Line Items]
Financial covenant, ratio of indebtedness to consolidated total capitalization minimum	0.65
SJG Commercial Paper Program [Member]
Line of Credit Facility [Line Items]
Total facility	200,000,000
Fixed maturities of notes, at maximum number of days (in days)	270 days
South Jersey Gas Company [Member]
Line of Credit Facility [Line Items]
Total facility	210,000,000
Usage	93,000,000
Available liquidity	117,000,000
South Jersey Gas Company [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Total facility	200,000,000
Usage	93,000,000
Available liquidity	107,000,000
Expiration date	May 2015
South Jersey Gas Company [Member] | Uncommitted Bank Lines [Member]
Line of Credit Facility [Line Items]
Total facility	10,000,000	[1]
Usage	0	[1]
Available liquidity	10,000,000	[1]
Expiration date	August 2013	[1]
South Jersey Industries Inc [Member]
Line of Credit Facility [Line Items]
Total facility	450,000,000
Usage	230,300,000
Available liquidity	219,700,000
South Jersey Industries Inc [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Total facility	400,000,000	[2]
Usage	180,300,000	[2]
Available liquidity	219,700,000	[2]
Expiration date	February 2018 (A)	[2]
South Jersey Industries Inc [Member] | Term Line of Credit [Member]
Line of Credit Facility [Line Items]
Total facility	50,000,000
Usage	50,000,000
Available liquidity	$ 0
Expiration date	November 2013

[1] Although there can be no assurances, SJG anticipates renewing the remaining line of credit during the third quarter 2013.

[2] Includes letters of credit outstanding in the amount of $27.6 million.

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STOCK-BASED COMPENSATION PLAN (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares in the aggregate that may be issued under the 1997 Stock-Based Compensation Plan	2,000,000		2,000,000
Number of options granted			0	0
Fair value per share (in dollars per share)	$ 50.780		$ 50.780
Cost	$ 757,000	$ 752,000	$ 1,521,000	$ 1,402,000
Capitalized	(63,000)	(58,000)	(126,000)	(115,000)
Net expense	694,000	694,000	1,395,000	1,287,000
Unrecognized compensation cost of awards granted under the plan	4,000,000		4,000,000
Weighted average period over which unrecognized compensation cost is to be recognized (in years)			1 year 10 months 24 days
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-beginning balance (in dollars per share)			$ 51.292
Weighted average fair value nonvested shares-granted during the period (in dollars per share)			$ 48.488
Weighted average fair value nonvested shares-cancelled/forfeited during the period (in dollars per share)			$ 50.302
Weighted average fair value nonvested shares-vested during the period (in dollars per share)			$ 45.809
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 50.780		$ 50.780
Officers and Key Employees [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted			56,464	40,955
Vesting period of shares (in years)			3 years
The range of the actual amount of shares that ultimately vest of the original share units granted (in hundredths)			0% to 150%
Shares outstanding (in shares)	135,775		135,775
Cost	566,000	524,000	1,139,000	1,048,000
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)			81,005
Granted (in shares)			56,464	40,955
Cancelled/Forfeited (in shares)			(1,694)
Vested (in shares)			0
Nonvested shares outstanding, ending balance (in shares)	135,775		135,775
Additional disclosures [Abstract]
Number of shares awarded during the period			66,077	33,322
Market value of shares awarded			3,300,000	1,900,000
Officers and Key Employees [Member] | Grant Date January 2011 - TSR [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	40,069		40,069
Fair value per share (in dollars per share)	$ 50.940		$ 50.940
Expected volatility (in hundredths)			27.50%
Risk-free interest rate (in hundredths)			1.01%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	40,069		40,069
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 50.940		$ 50.940
Officers and Key Employees [Member] | Grant Date January 2012 - TSR [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	20,090		20,090
Fair value per share (in dollars per share)	$ 51.230		$ 51.230
Expected volatility (in hundredths)			22.50%
Risk-free interest rate (in hundredths)			0.43%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	20,090		20,090
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 51.230		$ 51.230
Officers and Key Employees [Member] | Grant Date January 2012 - EPS [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	20,090		20,090
Fair value per share (in dollars per share)	$ 56.930		$ 56.930
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	20,090		20,090
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 56.930		$ 56.930
Officers and Key Employees [Member] | Grant Date January 2013 - TSR [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	27,763		27,763
Fair value per share (in dollars per share)	$ 44.380		$ 44.380
Expected volatility (in hundredths)			21.10%
Risk-free interest rate (in hundredths)			0.40%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	27,763		27,763
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 44.380		$ 44.380
Officers and Key Employees [Member] | Grant Date January 2013 - EPS [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	27,763		27,763
Fair value per share (in dollars per share)	$ 51.180		$ 51.180
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	27,763		27,763
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 51.180		$ 51.180
Directors [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted			12,285	9,904
Vesting period of shares (in years)			3 years
Shares Vested, Directors (in hundredths)	100.00%		100.00%
Shares outstanding (in shares)	19,617		19,617
Cost	191,000	228,000	382,000	354,000
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, beginning balance (in shares)			27,688
Granted (in shares)			12,285	9,904
Cancelled/Forfeited (in shares)			0
Vested (in shares)			(20,356)
Nonvested shares outstanding, ending balance (in shares)	19,617		19,617
Additional disclosures [Abstract]
Market value of shares awarded			$ 600,000	$ 600,000
Directors [Member] | Grant Date January 2011 [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	7,332		7,332
Fair value per share (in dollars per share)	$ 52.940		$ 52.940
Expected volatility (in hundredths)			0.00%
Risk-free interest rate (in hundredths)			0.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	7,332		7,332
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 52.940		$ 52.940
Directors [Member] | Grant Date January 2013 [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares outstanding (in shares)	12,285		12,285
Fair value per share (in dollars per share)	$ 51.740		$ 51.740
Expected volatility (in hundredths)			0.00%
Risk-free interest rate (in hundredths)			0.00%
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Nonvested shares outstanding, ending balance (in shares)	12,285		12,285
Additional disclosures [Abstract]
Weighted average fair value nonvested shares-ending balance (in dollars per share)	$ 51.740		$ 51.740
Minimum [Member] | Officers and Key Employees [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted			0.00%
Maximum [Member] | Officers and Key Employees [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted			150.00%
Stock Appreciation Rights (SARs) [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Number of shares granted			0	0
Restricted stock award activity, excluding accrued dividend equivalents [Roll Forward]
Granted (in shares)			0	0

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FINANCIAL INSTRUMENTS 3 (Details) (USD $)	6 Months Ended	12 Months Ended
	Jun. 30, 2013	Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]
Finance obligation to ACB Energy Partners LLC	$ 21,150,000	$ 21,646,000
Estimated fair value of long-term debt	649,700,000	682,300,000
Carrying amount of long-term debt	626,400,000	626,400,000
Energenic US LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity interest of Marina in Energenic	50.00%
Marina Energy LLC [Member] | Energenic US LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity interest of Marina in Energenic	50.00%
Other construction costs	23,600,000	23,600,000
Finance obligation to ACB Energy Partners LLC	$ 21,100,000	$ 21,600,000

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DERIVATIVE INSTRUMENTS 2 (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	$ 48,468	$ 36,539
Fair value Derivative Liabilities	72,633	42,693
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	48,468	36,539
Fair value Derivative Liabilities	72,633	42,693
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-Current [Member]
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	33,826	24,242
Fair value Derivative Liabilities	37,979	23,828
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-NonCurrent [Member]
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	14,642	12,297
Fair value Derivative Liabilities	25,563	5,403
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Other [Member]
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$ 9,091	$ 13,462

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)

6 Months Ended

Jun. 30, 2013

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, 2013	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,859	$	7,859	$	—	$	—
Derivatives – Energy Related Assets (B)	48,468		6,444		17,811		24,213
	$	56,327	$	14,303	$	17,811	$	24,213
Liabilities
Derivatives – Energy Related Liabilities (B)	$	63,542	$	4,065	$	26,749	$	32,728
Derivatives – Other (C)	9,091		—		9,091		—
	$	72,633	$	4,065	$	35,840	$	32,728

As of December 31, 2012	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,538	$	787	$	6,751	$	—
Derivatives – Energy Related Assets (B)	36,539		9,404		16,205		10,930
	$	44,077	$	10,191	$	22,956	$	10,930
Liabilities
Derivatives – Energy Related Liabilities (B)	$	29,231	$	5,399	$	15,664	$	8,168
Derivatives – Other (C)	13,462		—		13,462		—
	$	42,693	$	5,399	$	29,126	$	8,168

(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 are 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 are 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, 2013		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$17,019	$28,069	Discounted Cash Flow	Forward price (per dt)	$(1.20) - $3.58 [$(0.49)]
Forward Contract - Electric	$7,194	$4,659	Discounted Cash Flow	Fixed electric load profile (on-peak)	19.72% - 100.00% [60.44%]
				Fixed electric load profile (off-peak)	0.00% - 80.28% [39.56%]

Type	Fair Value at December 31, 2012				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	4,340	$	4,986	Discounted Cash Flow	Forward price (per dt)	$(0.35) - $2.92 [$(0.12)]
Forward Contract - Electric	$	6,590	$	3,182	Discounted Cash Flow	Fixed electric load profile (on-peak)	21.62% - 100.00% [53.64%]
						Fixed electric load profile (off-peak)	0.00% - 78.38% [46.36%]

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, 2013 and 2012, using significant unobservable inputs (Level 3), are as follows (in thousands):

	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
Balance at beginning of period	$	1,627		$	2,762
Total losses realized/unrealized included in earnings	(12,022		)	(12,723		)
Transfers in/(out) of Level 3 (A)	928			928
Settlements	952			518
Balance at June 30	$	(8,515	)	$	(8,515	)

(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, 2013, $0.9 million of net derivatives assets were transferred from Level 2 to Level 3, due to decreased observability of market data. The transfer was recognized as of the end of the second quarter.

	Three Months Ended June 30, 2012			Six Months Ended June 30, 2012
Balance at beginning of period	(1,958		)	(5,958		)
Total losses realized/unrealized included in earnings	3,306			3,475
Settlements	1,730			5,561
Balance at June 30	$	3,078		$	3,078

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REGULATORY ASSETS & REGULATORY LIABILITIES (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 326,406	$ 352,656
Environmental Remediation Costs: Expended - Net [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	30,387	37,892
Environmental Restoration Costs: Liability for Future Expenditures [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	110,148	107,410
Deferred Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	30,594	30,199
Deferred Pension and Other Postretirement Benefit Costs [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	95,897	95,897
Conservation Incentive Program Receivable [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	11,824	31,686
Societal Benefit Costs Receivable [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	12,502	12,801
Premium for Early Retirement of Debt [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	997	1,075
Deferred Interest Rate Contracts [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	5,164	7,761
Energy Efficiency Tracker [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	11,949	12,306
Pipeline Supplier Service Charges [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	7,938	8,771
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 9,006	$ 6,858

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COMMON STOCK (Tables)

6 Months Ended

Jun. 30, 2013

Common Stock [Abstract]

Common stock shares issued and outstanding

The following shares were issued and outstanding at June 30:

	2013
Beginning Balance, January 1	31,653,262
New Issues During the Period:
Dividend Reinvestment Plan	231,485
Stock-Based Compensation Plan	78,363
Ending Balance, June 30	31,963,110

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2013

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.

▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects.

▪ 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 Energy Service Plus, LLC (SJESP) services residential and 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, and the installation of small commercial HVAC systems.

▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.

BASIS OF PRESENTATION — The condensed consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which we have a controlling interest. We eliminate 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 2012 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.

Certain reclassifications have been made to the prior period segment disclosures to conform to the current period presentation. In all periods presented, net receivables between the Discontinued Operations segment and the Corporate and Services segment have been reclassified in the Identifiable Assets Segment disclosure in Note 6.

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). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both utility revenue and cost of sales and totaled $0.7 million and $0.9 million for the three months ended June 30, 2013 and 2012, respectively, and $2.9 million and $3.4 million for the six months ended June 30, 2013 and 2012, respectively. The TEFA is subject to a planned phase-out which decreases the assessment in increments of 25% in 2012 and 2013 and is eliminated after December 31, 2013.

IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. The Company recorded a $1.1 million impairment charge during the six months ended June 30, 2012 related to certain shallow wells in the Marcellus region as discussed under “Gas Exploration and Development”.  For the six months ended June 30, 2013, no impairments were identified.

GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. No impairment was recorded during the six months ended June 30, 2013. During the six months ended June 30, 2012, the Company recorded $1.1 million of impairment charges within Other Income and Expense on the condensed consolidated statement of income due to a reduction in the expected cash flows to be received from certain shallow wells in the Marcellus region. As of both June 30, 2013 and December 31, 2012, $9.0 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, 2013 and December 31, 2012, SJI held 134,783 and 145,414 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 the non-regulated entities 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 2013 and 2012 had, or is expected to have, a material impact on the condensed consolidated financial statements.

In January 2012, the FASB issued Accounting Standards Update (ASU) 2011-11, Enhanced Disclosure Requirements Concerning Offsetting of Financial Assets and Financial Liabilities. This ASU amends ASC 210-20 to add disclosure requirements in respect of the offsetting of financial assets and financial liabilities. In February 2013, the FASB issued ASU 2013-01 Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which amends and clarifies the scope of the balance sheet offsetting disclosures required through ASU 2011-11. The new guidance is effective for fiscal years beginning on or after January 1, 2013. The adoption of this guidance modified the disclosures around derivative instruments, but did not have an impact on the Company's financial statement results.

In February 2013, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.

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DISCONTINUED OPERATIONS AND AFFILIATIONS

6 Months Ended

Jun. 30, 2013

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, were (in thousands, except per share amounts):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Loss Before Income Taxes:
Sand Mining	$	(20	)	$	(705	)	$	(92	)	$	(901	)
Fuel Oil	(23		)	(61		)	(675		)	(75		)
Income Tax Benefits	15			268			268			342
Loss from Discontinued Operations — Net	$	(28	)	$	(498	)	$	(499	)	$	(634	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic	$	(0.001	)	$	(0.016	)	$	(0.015	)	$	(0.021	)
Diluted	$	(0.001	)	$	(0.016	)	$	(0.016	)	$	(0.021	)

AFFILIATIONS — The following affiliated entities are accounted for under the equity method:

Energenic – US, LLC (Energenic) - Marina and a joint venture partner formed Energenic, in which Marina has a 50% equity interest. Energenic develops and operates on-site, self-contained, energy-related projects.

In April 2012, Energenic acquired The Energy Network, LLC, a holding company for the Hartford Steam Company, TEN Companies and CNE Power I, LLC. In conjunction with this acquisition, Marina provided $35.4 million of advances to Energenic, which was repaid by Energenic during the second quarter of 2013 as permanent financing was obtained.

Potato Creek, LLC (Potato Creek) - SJI and a joint venture partner formed Potato Creek, in which SJI has a 30% equity interest.  Potato Creek owns and manages the oil, gas and mineral rights of certain real estate in Pennsylvania.

LVE Energy Partners, LLC (LVE) - In March 2013, substantially all of the assets of Marina's joint venture, LVE, an entity in which Marina has a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.6 million. See Note 11.

During the first six months of 2013 and 2012, the Company made investments in, and provided net advances to, unconsolidated affiliates of $7.3 million and $82.5 million, respectively. These amounts do not include the cash proceeds from LVE and the repayment of the advances to Energenic as discussed above. The purpose of these investments and advances was to cover certain project related costs of affiliates.   As of June 30, 2013 and December 31, 2012, the outstanding balance on these Notes Receivable – Affiliate was $71.1 million and $156.7 million, respectively. Approximately $64.1 million of these notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025. The remaining $7.0 million of these notes are unsecured, and are either non-interest bearing or accrue interest at variable rates and are to be repaid when the affiliate secures permanent financing.

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, 2013, the Company had a net asset of approximately $78.0 million included in Investment in Affiliates and Other Noncurrent Liabilities on the condensed consolidated balance sheets related to equity method investees, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of June 30, 2013 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $150.6 million.

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SEGMENTS OF BUSINESS

6 Months Ended

Jun. 30, 2013

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. Gas Utility Operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers. Wholesale Energy Operations include SJRG’s and SJEX's activities. 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, and the installation of small commercial HVAC systems.  The Retail Energy Operations caption includes Retail Gas and Other, Retail Electric, 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 June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Operating Revenues:
Gas Utility Operations	$	66,536		$	59,177		$	240,634		$	238,613
Wholesale Energy Operations	(10,699		)	(471		)	(4,482		)	17,171
Retail Energy Operations:
Retail Gas and Other Operations	24,585			13,600			58,698			31,792
Retail Electric Operations	31,419			38,365			62,148			88,552
On-Site Energy Production	9,965			9,356			19,059			17,257
Appliance Service Operations	3,133			3,578			6,441			6,860
Subtotal Retail Energy Operations	69,102			64,899			146,346			144,461
Corporate & Services	7,362			6,331			15,842			13,045
Subtotal	132,301			129,936			398,340			413,290
Intersegment Sales	(9,709		)	(8,023		)	(20,118		)	(16,545		)
Total Operating Revenues	$	122,592		$	121,913		$	378,222		$	396,745

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Operating Income:
Gas Utility Operations	$	8,069		$	7,465		$	65,864		$	66,320
Wholesale Energy Operations	(19,200		)	(2,843		)	(24,357		)	7,829
Retail Energy Operations:
Retail Gas and Other Operations	(160		)	(395		)	(132		)	(547		)
Retail Electric Operations	(337		)	5,110			127			10,054
On-Site Energy Production	268			684			(905		)	346
Appliance Service Operations	799			222			785			(219		)
Subtotal Retail Energy Operations	570			5,621			(125		)	9,634
Corporate and Services	(32		)	14			4			(18		)
Total Operating (Loss) Income	$	(10,593	)	$	10,257		$	41,386		$	83,765
Depreciation and Amortization:
Gas Utility Operations	$	12,929		$	11,130		$	23,953		$	22,092
Wholesale Energy Operations	55			64			106			117
Retail Energy Operations:
Retail Gas and Other Operations	21			23			43			31
On-Site Energy Production	3,958			2,722			6,970			4,726
Appliance Service Operations	72			78			146			162
Subtotal Retail Energy Operations	4,051			2,823			7,159			4,919
Corporate and Services	221			171			446			335
Total Depreciation and Amortization	$	17,256		$	14,188		$	31,664		$	27,463
Interest Charges:
Gas Utility Operations	$	2,789		$	3,771		$	5,750		$	7,960
Wholesale Energy Operations	33			72			85			158
Retail Energy Operations:
Retail Gas and Other Operations	67			13			143			51
On-Site Energy Production	307			1,215			1,710			2,234
Subtotal Retail Energy Operations	374			1,228			1,853			2,285
Corporate and Services	1,212			837			2,720			1,558
Subtotal	4,408			5,908			10,408			11,961
Intersegment Borrowings	(988		)	(713		)	(2,280		)	(1,273		)
Total Interest Charges	$	3,420		$	5,195		$	8,128		$	10,688
Income Taxes:
Gas Utility Operations	$	2,269		$	1,887		$	23,040		$	22,864
Wholesale Energy Operations	(7,710		)	(1,028		)	(9,691		)	2,953
Retail Energy Operations:
Retail Gas and Other Operations	(52		)	(90		)	220			94
Retail Electric Operations	(139		)	2,087			51			4,107
On-Site Energy Production	(6,466		)	(4,056		)	(18,030		)	(15,230		)
Appliance Service Operations	338			109			342			(54		)
Subtotal Retail Energy Operations	(6,319		)	(1,950		)	(17,417		)	(11,083		)
Corporate and Services	128			19			208			78
Total Income Tax (Benefit) Expense	$	(11,632	)	$	(1,072	)	$	(3,860	)	$	14,812

	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
Property Additions:
Gas Utility Operations	$	44,764	$	40,220	$	81,806	$	80,876
Wholesale Energy Operations	25		8		34		12
Retail Energy Operations:
Retail Gas and Other Operations	35		50		37		103
On-Site Energy Production	14,949		5,705		17,526		11,002
Appliance Service Operations	—		2		—		2
Subtotal Retail Energy Operations	14,984		5,757		17,563		11,107
Corporate and Services	1,126		1,254		1,864		1,659
Total Property Additions	$	60,899	$	47,239	$	101,267	$	93,654

	June 30, 2013			December 31, 2012
Identifiable Assets (See Note 1):
Gas Utility Operations	$	1,834,645		$	1,786,459
Wholesale Energy Operations	250,792			204,358
Retail Energy Operations:
Retail Gas and Other Operations	32,152			39,481
Retail Electric Operations	28,528			21,919
On-Site Energy Production	472,603			543,416
Appliance Service Operations	2,748			3,244
Subtotal Retail Energy Operations	536,031			608,060
Discontinued Operations	1,886			78
Corporate and Services	295,085			337,010
Intersegment Assets	(263,942		)	(304,525		)
Total Identifiable Assets	$	2,654,497		$	2,631,440

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COMMON STOCK

6 Months Ended

Jun. 30, 2013

Common Stock [Abstract]

Common Stock

COMMON STOCK:

The following shares were issued and outstanding at June 30:

	2013
Beginning Balance, January 1	31,653,262
New Issues During the Period:
Dividend Reinvestment Plan	231,485
Stock-Based Compensation Plan	78,363
Ending Balance, June 30	31,963,110

The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $13.6 million was recorded in Premium on Common Stock.

EARNINGS PER COMMON SHARE (EPS) — Basic EPS is based on the weighted-average number of common shares outstanding.  The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 63,174 and 79,355 for the three months ended June 30, 2013 and 2012, respectively, and 58,374 and 76,313 for the six months ended June 30, 2013 and 2012, 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 $12.5 million and $9.3 million of equity capital through the DRP during the six months ended June 30, 2013 and 2012, respectively.

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SEGMENTS OF BUSINESS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating revenues	$ 122,592	$ 121,913	$ 378,222	$ 396,745
Operating income (loss)	(10,593)	10,257	41,386	83,765
Depreciation and amortization	17,256	14,188	31,664	27,463
Interest charges	3,420	5,195	8,128	10,688
Income taxes	(11,632)	(1,072)	(3,860)	14,812
Property additions	60,899	47,239	101,267	93,654
Indentifiable assets	2,654,497		2,654,497		2,631,440
Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	132,301	129,936	398,340	413,290
Interest charges	4,408	5,908	10,408	11,961
Operating Segments [Member] | Gas Utility Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	66,536	59,177	240,634	238,613
Operating income (loss)	8,069	7,465	65,864	66,320
Depreciation and amortization	12,929	11,130	23,953	22,092
Interest charges	2,789	3,771	5,750	7,960
Income taxes	2,269	1,887	23,040	22,864
Property additions	44,764	40,220	81,806	80,876
Indentifiable assets	1,834,645		1,834,645		1,786,459
Operating Segments [Member] | Wholesale Energy Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	(10,699)	(471)	(4,482)	17,171
Operating income (loss)	(19,200)	(2,843)	(24,357)	7,829
Depreciation and amortization	55	64	106	117
Interest charges	33	72	85	158
Income taxes	(7,710)	(1,028)	(9,691)	2,953
Property additions	25	8	34	12
Indentifiable assets	250,792		250,792		204,358
Operating Segments [Member] | Retail Energy Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	69,102	64,899	146,346	144,461
Operating income (loss)	570	5,621	(125)	9,634
Depreciation and amortization	4,051	2,823	7,159	4,919
Interest charges	374	1,228	1,853	2,285
Income taxes	(6,319)	(1,950)	(17,417)	(11,083)
Property additions	14,984	5,757	17,563	11,107
Indentifiable assets	536,031		536,031		608,060
Operating Segments [Member] | Retail Energy Operations [Member] | Retail Gas and Other Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	24,585	13,600	58,698	31,792
Operating income (loss)	(160)	(395)	(132)	(547)
Depreciation and amortization	21	23	43	31
Interest charges	67	13	143	51
Income taxes	(52)	(90)	220	94
Property additions	35	50	37	103
Indentifiable assets	32,152		32,152		39,481
Operating Segments [Member] | Retail Energy Operations [Member] | Retail Electric Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	31,419	38,365	62,148	88,552
Operating income (loss)	(337)	5,110	127	10,054
Income taxes	(139)	2,087	51	4,107
Indentifiable assets	28,528		28,528		21,919
Operating Segments [Member] | Retail Energy Operations [Member] | On-site Energy Production [Member]
Segment Reporting Information [Line Items]
Operating revenues	9,965	9,356	19,059	17,257
Operating income (loss)	268	684	(905)	346
Depreciation and amortization	3,958	2,722	6,970	4,726
Interest charges	307	1,215	1,710	2,234
Income taxes	(6,466)	(4,056)	(18,030)	(15,230)
Property additions	14,949	5,705	17,526	11,002
Indentifiable assets	472,603		472,603		543,416
Operating Segments [Member] | Retail Energy Operations [Member] | Appliance Service Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	3,133	3,578	6,441	6,860
Operating income (loss)	799	222	785	(219)
Depreciation and amortization	72	78	146	162
Income taxes	338	109	342	(54)
Property additions	0	2	0	2
Indentifiable assets	2,748		2,748		3,244
Operating Segments [Member] | Corporate and Services [Member]
Segment Reporting Information [Line Items]
Operating revenues	7,362	6,331	15,842	13,045
Operating income (loss)	(32)	14	4	(18)
Depreciation and amortization	221	171	446	335
Interest charges	1,212	837	2,720	1,558
Income taxes	128	19	208	78
Property additions	1,126	1,254	1,864	1,659
Indentifiable assets	295,085		295,085		337,010
Discontinued Operations [Member]
Segment Reporting Information [Line Items]
Indentifiable assets	1,886		1,886		78
Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Operating revenues	(9,709)	(8,023)	(20,118)	(16,545)
Interest charges	(988)	(713)	(2,280)	(1,273)
Indentifiable assets	$ (263,942)		$ (263,942)		$ (304,525)

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PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)

6 Months Ended

Jun. 30, 2013

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, 2013 and 2012, 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 June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Service Cost	$	1,332		$	1,078		$	2,710		$	2,267
Interest Cost	2,387			2,412			4,719			4,811
Expected Return on Plan Assets	(2,968		)	(2,411		)	(5,957		)	(5,171		)
Amortizations:
Prior Service Cost	62			63			125			125
Actuarial Loss	2,332			2,060			4,503			3,815
Net Periodic Benefit Cost	3,145			3,202			6,100			5,847
Capitalized Benefit Costs	(1,268		)	(1,228		)	(2,435		)	(2,207		)
Total Net Periodic Benefit Expense	$	1,877		$	1,974		$	3,665		$	3,640

	Other Postretirement Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Service Cost	$	259		$	225		$	570		$	518
Interest Cost	665			733			1,365			1,501
Expected Return on Plan Assets	(601		)	(494		)	(1,189		)	(1,053		)
Amortizations:
Prior Service Credits	(71		)	(71		)	(142		)	(142		)
Actuarial Loss	410			482			869			862
Net Periodic Benefit Cost	662			875			1,473			1,686
Capitalized Benefit Costs	(248		)	(329		)	(570		)	(631		)
Total Net Periodic Benefit Expense	$	414		$	546		$	903		$	1,055

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ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)

6 Months Ended

Jun. 30, 2013

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, 2013 (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, 2013 (a)	$	(23,437	)	$	(2,896	)	$	20		$	14	$	(26,299	)
Other comprehensive income before reclassifications	—			—			(23		)	—		(23		)
Amounts reclassified from AOCL (b)	—			66			—			22		88
Net current period other comprehensive income (loss)	—			66			(23		)	22		65
Balance at June 30, 2013 (a)	$	(23,437	)	$	(2,830	)	$	(3	)	$	36	$	(26,234	)

	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, 2013 (a)	$	(23,437	)	$	(2,962	)	$	294		$	(5,000	)	$	(31,105	)
Other comprehensive income before reclassifications	—			—			192			—			192
Amounts reclassified from AOCL (b)	—			132			(489		)	5,036			4,679
Net current period other comprehensive income (loss)	—			132			(297		)	5,036			4,871
Balance at June 30, 2013 (a)	$	(23,437	)	$	(2,830	)	$	(3	)	$	36		$	(26,234	)

(a) Determined using a combined statutory tax rate of 41%.

(b) See table below.

Reclassifications out of AOCL

The following table provides details about reclassifications out of AOCL for the three and six months ended June 30, 2013:

	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Consolidated Statements of Income
	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	112		$	224		Interest Charges
Income Taxes	(46		)	(92		)	Income Taxes (a)
	$	66		$	132
Unrealized Gain on Available-for-Sale Securities	$	—		$	(827	)	Other Income
Income Taxes	—			338			Income Taxes (a)
	$	—		$	(489	)
Loss of Affiliated Companies	$	35		$	8,511		Equity in Loss of Affiliated Companies
Income Taxes	(13		)	(3,475		)	Income Taxes (a)
	$	22		$	5,036
Losses from reclassifications for the period net of tax	$	88		$	4,679

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COMMON STOCK (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Common Stock [Roll Forward]
Beginning balance (in shares)			31,653,262
New issues during period [Abstract]
Dividend reinvestment plan (in shares)			231,485
Stock-based compensation plan (in shares)			78,363
Ending balance (in shares)	31,963,110		31,963,110
Par value of common stock (in dollars per share)	$ 1.25		$ 1.25
Net excess over par value recorded in premium on common stock			$ 13,600,000
Incremental shares included in diluted earnings per share (in shares)	63,174	79,355	58,374	76,313
Proceeds from sale of common stock			$ 12,502,000	$ 9,256,000

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ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				6 Months Ended
	Jun. 30, 2013		Jun. 30, 2012		Jun. 30, 2013		Jun. 30, 2012
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	$ (26,299)	[1]			$ (31,105)	[1]
Other comprehensive income before reclassifications	(23)				192
Amounts reclassified from AOCL	88	[2]			4,679	[2]
Other Comprehensive Income (Loss) - Net of Tax	65	[1]	(231)	[1]	4,871	[1]	(1,972)	[1]
Ending balance	(26,234)	[1]			(26,234)	[1]
Combined statutory tax rate	41.00%		41.00%		41.00%		41.00%
Postretirement Liability Adjustment [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	(23,437)	[1]			(23,437)	[1]
Other comprehensive income before reclassifications	0				0
Amounts reclassified from AOCL	0	[2]			0	[2]
Other Comprehensive Income (Loss) - Net of Tax	0				0
Ending balance	(23,437)	[1]			(23,437)	[1]
Unrealized Gain (Loss) on Derivatives-Other [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	(2,896)	[1]			(2,962)	[1]
Other comprehensive income before reclassifications	0				0
Amounts reclassified from AOCL	66	[2]			132	[2]
Other Comprehensive Income (Loss) - Net of Tax	66				132
Ending balance	(2,830)	[1]			(2,830)	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	20	[1]			294	[1]
Other comprehensive income before reclassifications	(23)				192
Amounts reclassified from AOCL	0	[2]			(489)	[2]
Other Comprehensive Income (Loss) - Net of Tax	(23)				(297)
Ending balance	(3)	[1]			(3)	[1]
Other Comprehensive Income (Loss) of Affiliated Companies [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	14	[1]			(5,000)	[1]
Other comprehensive income before reclassifications	0				0
Amounts reclassified from AOCL	22	[2]			5,036	[2]
Other Comprehensive Income (Loss) - Net of Tax	22				5,036
Ending balance	$ 36	[1]			$ 36	[1]

[1] Determined using a combined statutory tax rate of 41%.

[2] See table below.

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DERIVATIVE INSTRUMENTS 3 (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013		Dec. 31, 2012
Commodity Contract [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	$ 48,468		$ 36,539
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	48,468		36,539
Gross amounts not offset in the balance sheet, Financial Instruments	(10,162)	[1]	(12,975)	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		0
Net amount	38,306		23,564
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(63,542)		(29,231)
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	(63,542)		(29,231)
Gross amounts not offset in the balance sheet, Financial Instruments	10,162	[2]	12,975	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	24,078		6,347
Net amount	(29,302)		(9,909)
Interest Rate Contract [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(9,091)		(13,462)
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	(9,091)		(13,462)
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	$ (9,091)		$ (13,462)

[1] The balances at June 30, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.

[2] The balances at June 30, 2013 and December 31, 2012 were related to derivative assets which can be net settled against derivative liabilities.

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PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) (USD $)	1 Months Ended		3 Months Ended		6 Months Ended
	Jan. 31, 2013	Jan. 31, 2012	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Pension Benefits [Member]
Net periodic benefit cost [Abstract]
Service cost			$ 1,332,000	$ 1,078,000	$ 2,710,000	$ 2,267,000
Interest cost			2,387,000	2,412,000	4,719,000	4,811,000
Expected return on plan assets			(2,968,000)	(2,411,000)	(5,957,000)	(5,171,000)
Amortizations [Abstract]
Prior service cost (credits)			62,000	63,000	125,000	125,000
Actuarial loss			2,332,000	2,060,000	4,503,000	3,815,000
Net periodic benefit cost prior to ERIP and capitalized benefit costs			3,145,000	3,202,000	6,100,000	5,847,000
Capitalized benefit costs			(1,268,000)	(1,228,000)	(2,435,000)	(2,207,000)
Total net periodic benefit expense			1,877,000	1,974,000	3,665,000	3,640,000
Contributions	12,700,000	25,000,000
Other Postretirement Benefits [Member]
Net periodic benefit cost [Abstract]
Service cost			259,000	225,000	570,000	518,000
Interest cost			665,000	733,000	1,365,000	1,501,000
Expected return on plan assets			(601,000)	(494,000)	(1,189,000)	(1,053,000)
Amortizations [Abstract]
Prior service cost (credits)			(71,000)	(71,000)	(142,000)	(142,000)
Actuarial loss			410,000	482,000	869,000	862,000
Net periodic benefit cost prior to ERIP and capitalized benefit costs			662,000	875,000	1,473,000	1,686,000
Capitalized benefit costs			(248,000)	(329,000)	(570,000)	(631,000)
Total net periodic benefit expense			414,000	546,000	903,000	1,055,000
Defined benefit plan regulatory obligation to contribute to the plan during the period			3,600,000		3,600,000
Supplemental Employee Retirement Plans, Defined Benefit [Member]
Amortizations [Abstract]
Estimated future contributions			$ 1,300,000		$ 1,300,000

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $) In Thousands, unless otherwise specified	3 Months Ended				6 Months Ended
	Jun. 30, 2013		Jun. 30, 2012		Jun. 30, 2013		Jun. 30, 2012
Statement of Other Comprehensive Income [Abstract]
Net Income	$ 888		$ 10,334		$ 43,754		$ 64,409
Other Comprehensive Income (Loss), Net of Tax:
Unrealized (Loss) Gain on Available-for-Sale Securities	(23)	[1]	(136)	[1]	(297)	[1]	215	[1]
Unrealized Gain (Loss) on Derivatives - Other	66	[1]	(415)	[1]	132	[1]	(225)	[1]
Other Comprehensive Income (Loss) of Affiliated Companies	22	[1]	320	[1]	5,036	[1]	(1,962)	[1]
Other Comprehensive Income (Loss) - Net of Tax	65	[1]	(231)	[1]	4,871	[1]	(1,972)	[1]
Comprehensive Income	$ 953		$ 10,103		$ 48,625		$ 62,437
Combined statutory tax rate	41.00%		41.00%		41.00%		41.00%

[1] Determined using a combined statutory tax rate of 41%.

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PENSION AND OTHER POSTRETIREMENT BENEFITS

6 Months Ended

Jun. 30, 2013

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, 2013 and 2012, 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 June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Service Cost	$	1,332		$	1,078		$	2,710		$	2,267
Interest Cost	2,387			2,412			4,719			4,811
Expected Return on Plan Assets	(2,968		)	(2,411		)	(5,957		)	(5,171		)
Amortizations:
Prior Service Cost	62			63			125			125
Actuarial Loss	2,332			2,060			4,503			3,815
Net Periodic Benefit Cost	3,145			3,202			6,100			5,847
Capitalized Benefit Costs	(1,268		)	(1,228		)	(2,435		)	(2,207		)
Total Net Periodic Benefit Expense	$	1,877		$	1,974		$	3,665		$	3,640

	Other Postretirement Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Service Cost	$	259		$	225		$	570		$	518
Interest Cost	665			733			1,365			1,501
Expected Return on Plan Assets	(601		)	(494		)	(1,189		)	(1,053		)
Amortizations:
Prior Service Credits	(71		)	(71		)	(142		)	(142		)
Actuarial Loss	410			482			869			862
Net Periodic Benefit Cost	662			875			1,473			1,686
Capitalized Benefit Costs	(248		)	(329		)	(570		)	(631		)
Total Net Periodic Benefit Expense	$	414		$	546		$	903		$	1,055

Capitalized benefit costs reflected in the table above relate to SJG’s construction program.

SJI contributed $12.7 million and $25.0 million to the pension plans in January 2013 and 2012, respectively. No additional contributions are expected to be made to the pension plans during 2013. Payments related to the unfunded supplemental executive retirement plan (SERP) are expected to approximate $1.3 million in 2013. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred.

See Note 12 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012, for additional information related to SJI’s pension and other postretirement benefits.

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CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013		Dec. 31, 2012
Property, Plant and Equipment:
Utility Plant, at original cost	$ 1,735,375		$ 1,658,790
Accumulated Depreciation	(384,762)		(373,199)
Nonutility Property and Equipment, at cost	351,091		328,638
Accumulated Depreciation	(43,589)		(36,208)
Property, Plant and Equipment - Net	1,658,115		1,578,021
Investments:
Available-for-Sale Securities	7,859		7,538
Restricted	31,783		17,903
Investment in Affiliates	78,388		75,825
Total Investments	118,030		101,266
Current Assets:
Cash and Cash Equivalents	2,260		4,638
Accounts Receivable	246,460		195,293
Unbilled Revenues	14,549		40,938
Provision for Uncollectibles	(6,943)		(5,924)
Notes Receivable - Affiliate	5,287		39,495
Natural Gas in Storage, average cost	58,440		55,517
Materials and Supplies, average cost	2,647		2,618
Prepaid Taxes	18,378		26,187
Derivatives - Energy Related Assets	33,826		24,242
Other Prepayments and Current Assets	18,103		11,833
Total Current Assets	393,007		394,837
Regulatory and Other Noncurrent Assets:
Regulatory Assets	326,406		352,656
Derivatives - Energy Related Assets	14,642		12,297
Unamortized Debt Issuance Costs	7,820		8,226
Notes Receivables-Affiliate	65,828		117,188
Contract Receivables	13,782		13,985
Other	56,867		52,964
Total Regulatory and Other Noncurrent Assets	485,345		557,316
Total Assets	2,654,497		2,631,440
Equity:
Common Stock	39,954		39,567
Premium on Common Stock	359,431		345,807
Treasury Stock (at par)	(169)		(182)
Accumulated Other Comprehensive Loss	(26,234)	[1]	(31,105)	[1]
Retained Earnings	397,611		382,127
Total Equity	770,593		736,214
Long-Term Debt	601,400		601,400
Total Capitalization	1,371,993		1,337,614
Current Liabilities:
Notes Payable	295,700		338,900
Current Portion of Long-Term Debt	25,000		25,000
Accounts Payable	192,381		193,331
Customer Deposits and Credit Balances	17,240		17,757
Environmental Remediation Costs	25,691		21,026
Taxes Accrued	2,462		2,156
Derivatives - Energy Related Liabilities	37,979		23,828
Deferred Income Taxes - Net	5,678		10,812
Deferred Contract Revenues	42		0
Dividends Payable	14,165		0
Interest Accrued	7,629		6,635
Pension Benefits	1,236		1,272
Other Current Liabilities	7,136		11,127
Total Current Liabilities	632,339		651,844
Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	291,928		289,489
Investment Tax Credits	489		618
Pension and Other Postretirement Benefits	97,283		105,168
Environmental Remediation Costs	88,379		91,072
Asset Retirement Obligations	40,067		39,385
Derivatives - Energy Related Liabilities	25,563		5,403
Derivatives - Other	9,091		13,462
Regulatory Liabilities	60,615		56,517
Finance Obligation	21,150		21,646
Other	15,600		19,222
Total Deferred Credits and Other Noncurrent Liabilities	650,165		641,982
Commitments and Contingencies (Note 11)
Total Capitalization and Liabilities	$ 2,654,497		$ 2,631,440

[1] Determined using a combined statutory tax rate of 41%.

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CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Operating Revenues:
Utility	$ 66,040	$ 59,056	$ 239,691	$ 238,258
Nonutility	56,552	62,857	138,531	158,487
Total Operating Revenues	122,592	121,913	378,222	396,745
Cost of Sales - (Excluding depreciation)
- Utility	25,611	20,286	102,766	106,551
- Nonutility	62,216	49,233	137,361	119,836
Operations	27,957	26,416	60,646	54,198
Maintenance	3,365	3,371	6,787	6,563
Depreciation	12,372	10,485	23,779	20,089
Energy and Other Taxes	1,664	1,865	5,497	5,743
Total Operating Expenses	133,185	111,656	336,836	312,980
Operating (Loss) Income	(10,593)	10,257	41,386	83,765
Other Income and Expense	2,665	3,658	6,534	5,531
Interest Charges	(3,420)	(5,195)	(8,128)	(10,688)
(Loss) Income Before Income Taxes	(11,348)	8,720	39,792	78,608
Income Tax Benefit (Expense)	11,632	1,072	3,860	(14,812)
Equity in Earnings of Affiliated Companies	632	1,040	601	1,247
Income from Continuing Operations	916	10,832	44,253	65,043
Loss from Discontinued Operations - (Net of tax benefit)	(28)	(498)	(499)	(634)
Net Income	$ 888	$ 10,334	$ 43,754	$ 64,409
Basic Earnings Per Common Share:
Continuing Operations (in dollars per share)	$ 0.029	$ 0.356	$ 1.389	$ 2.145
Discontinued Operations (in dollars per share)	$ (0.001)	$ (0.016)	$ (0.015)	$ (0.021)
Basic Earnings Per Common Share (in dollars per share)	$ 0.028	$ 0.340	$ 1.374	$ 2.124
Average Shares of Common Stock Outstanding - Basic (in shares)	31,949	30,393	31,853	30,321
Diluted Earnings Per Common Share:
Continuing Operations (in dollars per share)	$ 0.029	$ 0.355	$ 1.387	$ 2.140
Discontinued Operations (in dollars per share)	$ (0.001)	$ (0.016)	$ (0.016)	$ (0.021)
Diluted Earnings Per Common Share (in dollars per share)	$ 0.028	$ 0.339	$ 1.371	$ 2.119
Average Shares of Common Stock Outstanding - Diluted (in shares)	32,012	30,472	31,912	30,397
Dividends Declared per Common Share (in dollars per share)	$ 0.443	$ 0.403	$ 0.886	$ 0.806

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DERIVATIVE INSTRUMENTS 4 (Details) (USD $)	3 Months Ended				6 Months Ended
	Jun. 30, 2013		Jun. 30, 2012		Jun. 30, 2013		Jun. 30, 2012
Interest Rate Contracts [Abstract]
Losses recognized in OCI on effective portion	$ 0		$ (888,000)		$ 0		$ (752,000)
Losses reclassified from accumulated OCI into income	(112,000)	[1]	(183,000)	[1]	(224,000)	[1]	(370,000)	[1]
Gains or (losses) recognized in income on ineffective portion	0	[1]	0	[1]	0	[1]	0	[1]
Gain (loss) on energy related derivative instruments not designated as hedging instruments	(16,722,000)	[1]	3,308,000	[1]	(23,771,000)	[1]	10,279,000	[1]
Gain (loss) on interest rate derivative instruments not designated as hedging instruments	1,250,000	[2]	84,000	[2]	1,775,000	[2]	220,000	[2]
Derivative instruments not designated as hedging instruments, gain (loss), net	(15,472,000)		3,392,000		(21,996,000)		10,499,000
Realized losses, derivative instruments on energy-related contracts	1,300,000		5,700,000		200,000		10,700,000
Fair value derivative instruments with credit-risk-related features	29,500,000				29,500,000
Additional collateral, aggregate fair value	$ 25,100,000				$ 25,100,000

[1] Included in Operating Revenues - Non Utility

[2] Included in Interest Charges

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UNUSED LINES OF CREDIT (Tables)

6 Months Ended

Jun. 30, 2013

Line of Credit Facility [Abstract]

Schedule of lines of credit

Credit facilities and available liquidity as of June 30, 2013 were as follows (in thousands):

Company	Total Facility		Usage		Available Liquidity		Expiration Date
SJG:
Commercial Paper Program/Revolving Credit Facility	$	200,000	$	93,000	$	107,000	May 2015
Uncommitted Bank Lines (B)	10,000		—		10,000		August 2013
Total SJG	210,000		93,000		117,000
SJI:
Revolving Credit Facility	$	400,000	$	180,300	$	219,700	February 2018 (A)
Term Line of Credit	50,000		50,000		—		November 2013
Total SJI	450,000		230,300		219,700
Total	$	660,000	$	323,300	$	336,700

(A) Includes letters of credit outstanding in the amount of $27.6 million.

(B) Although there can be no assurances, SJG anticipates renewing the remaining line of credit during the third quarter 2013.

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STOCK-BASED COMPENSATION PLAN (Tables)

6 Months Ended

Jun. 30, 2013

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, 2013 and the assumptions used to estimate the fair value of the awards:

	Grant Date	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Officers & Key Employees -	Jan. 2011 - TSR	40,069	$	50.940	27.5	%	1.01	%
	Jan. 2012 - TSR	20,090	$	51.230	22.5	%	0.43	%
	Jan. 2012 - EPS	20,090	$	56.930	N/A		N/A
	Jan. 2013 - TSR	27,763	$	44.380	21.1	%	0.40	%
	Jan. 2013 - EPS	27,763	$	51.180	N/A		N/A
Directors -	Jan. 2011	7,332	$	52.940	—		—
	Jan. 2013	12,285	$	51.740	—		—

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, 2013 and 2012 (in thousands):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Officers & Key Employees	$	566		$	524		$	1,139		$	1,048
Directors	191			228			382			354
Total Cost	757			752			1,521			1,402
Capitalized	(63		)	(58		)	(126		)	(115		)
Net Expense	$	694		$	694		$	1,395		$	1,287

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, 2013, excluding accrued dividend equivalents:

	Officers &Other Key Employees		Directors		Weighted Average Fair Value
Nonvested Shares Outstanding, January 1, 2013	81,005		27,688		$	51.292
Granted	56,464		12,285		$	48.488
Cancelled/Forfeited	(1,694	)	—		$	50.302
Vested	—		(20,356	)	$	45.809
Nonvested Shares Outstanding, June 30, 2013	135,775		19,617		$	50.780

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REGULATORY ASSETS & REGULATORY LIABILITIES 2 (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 60,615	$ 56,517
Excess Plant Removal Costs [Member]
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	42,673	45,593
Deferred Revenues - Net [Member]
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	14,693	10,924
Other Regulatory Liablities [Member]
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 3,249	$ 0

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LONG-TERM DEBT (Details) (USD $)		1 Months Ended
	Jun. 30, 2013	Feb. 28, 2012 South Jersey Gas Company [Member] Series Due 2027, 7.7 Percent [Member] Medium-term Notes [Member]	Jun. 30, 2013 South Jersey Gas Company [Member] Series Due 2027, 7.7 Percent [Member] Medium-term Notes [Member]	Dec. 31, 2011 South Jersey Gas Company [Member] Series Due 2027, 7.7 Percent [Member] Medium-term Notes [Member]	Apr. 30, 2012 South Jersey Gas Company [Member] Series Due 2032, 3.74 Percent [Member] Medium-term Notes [Member]
Debt Instrument [Line Items]
Approved borrowing capacity				$ 200,000,000
Remaining balance available under note program			80,000,000
Debt called		35,000,000.0
Stated interest rate	7.50%	7.70%			3.74%
Premium in addition to par for called debt		2.00%
Debt issued					$ 35,000,000.0

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FINANCIAL INSTRUMENTS 2 (Details) (Derivatives Energy Related Assets [Member], Supplier Concentration Risk [Member], USD $) In Millions, unless otherwise specified	6 Months Ended
	Jun. 30, 2013
Derivatives Energy Related Assets [Member] | Supplier Concentration Risk [Member]
Concentration Risk [Line Items]
Amount of derivatives - energy related assets with single retail counterparty	$ 14.9
Percentage of derivatives - energy related assets with a single retail counterparty (in hundredths)	30.70%

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DISCONTINUED OPERATIONS AND AFFILIATIONS (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Loss before Income Taxes: [Abstract]
Income Tax Benefits	$ 15	$ 268	$ 268	$ 342
Loss from Discontinued Operations — Net	(28)	(498)	(499)	(634)
Earnings per common share from discontinued operations, net [Abstract]
Basic (in dollars per share)	$ (0.001)	$ (0.016)	$ (0.015)	$ (0.021)
Diluted (in dollars per share)	$ (0.001)	$ (0.016)	$ (0.016)	$ (0.021)
Sand Mining [Member]
Loss before Income Taxes: [Abstract]
(Loss) Income Before Income Taxes	(20)	(705)	(92)	(901)
Fuel Oil [Member]
Loss before Income Taxes: [Abstract]
(Loss) Income Before Income Taxes	$ (23)	$ (61)	$ (675)	$ (75)

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DISCONTINUED OPERATIONS AND AFFILIATIONS 2 (Details) (USD $)	6 Months Ended						1 Months Ended			6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012	Jun. 30, 2013 Energenic US LLC [Member]	Jun. 30, 2013 Potato Creek, LLC (Potato Creek) [Member]	Jun. 30, 2013 LVE Energy Partners, LLC (LVE) [Member]	Apr. 30, 2012 Marina Energy LLC [Member] Energenic US LLC [Member]	Jun. 30, 2013 Marina Energy LLC [Member] Energenic US LLC [Member]	Apr. 30, 2007 Marina Energy LLC [Member] LVE Energy Partners, LLC (LVE) [Member]	Jun. 30, 2013 LVE Energy Partners [Member] Marina Energy LLC [Member] LVE Energy Partners, LLC (LVE) [Member]
Affiliations [Abstract]
Equity interest (in hundredths)				50.00%	30.00%	50.00%		50.00%	50.00%
Advances							$ 35,400,000
Proceeds from sale of joint venture										57,600,000
Investments in unconsolidated affiliates	7,300,000	82,500,000
Notes Receivable - affiliate	71,100,000		156,700,000
Notes receivable, secured by property, plant and equipment of affiliates	64,100,000
Interest accrual on secured notes receivable (in hundredths)	7.50%
Repayment period, latest date	2025
Notes receivable - affiliate	5,287,000		39,495,000							7,000,000
Net asset - included in investment in affiliates and other noncurrent liabilities	78,000,000
Combined equity contributions and the notes receivable - affiliate	$ 150,600,000

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REGULATORY ASSETS & REGULATORY LIABILITIES

6 Months Ended

Jun. 30, 2013

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, 2012 which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012.

Regulatory Assets consisted of the following items (in thousands):

	June 30, 2013		December 31, 2012
Environmental Remediation Costs:
Expended - Net	$	30,387	$	37,892
Liability for Future Expenditures	110,148		107,410
Deferred Asset Retirement Obligation Costs	30,594		30,199
Deferred Pension and Other Postretirement Benefit Costs	95,897		95,897
Conservation Incentive Program Receivable	11,824		31,686
Societal Benefit Costs Receivable	12,502		12,801
Premium for Early Retirement of Debt	997		1,075
Deferred Interest Rate Contracts	5,164		7,761
Energy Efficiency Tracker	11,949		12,306
Pipeline Supplier Service Charges	7,938		8,771
Other Regulatory Assets	9,006		6,858
Total Regulatory Assets	$	326,406	$	352,656

CONSERVATION INCENTIVE PROGRAM (CIP) RECEIVABLE – The decrease in this receivable is primarily the result of colder weather experienced in the region during the 2012-2013 winter season compared with the prior winter season. The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. 

Regulatory Liabilities consisted of the following items (in thousands):

	June 30, 2013		December 31, 2012
Excess Plant Removal Costs	$	42,673	$	45,593
Deferred Revenues - Net	14,693		10,924
Other Regulatory Liabilities	3,249		—
Total Regulatory Liabilities	$	60,615	$	56,517

DEFERRED REVENUES – NET – Over/under collections of gas costs are monitored through SJG’s BGSS mechanism.  Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability.  Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval.  The BGSS increased from a $10.9 million regulatory liability at December 31, 2012 to a $14.7 million regulatory liability at June 30, 2013, primarily due to gas costs recovered from customers exceeding the actual cost of the commodity. SJG typically overcollects during the winter season when throughput is high and undercollects during the summer season when throughput is low.

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DERIVATIVE INSTRUMENTS (Tables)

6 Months Ended

Jun. 30, 2013

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, 2013 and December 31, 2012, are as follows (in thousands):

Derivatives not designated as hedging instruments under GAAP	June 30, 2013				December 31, 2012
	Assets		Liabilities		Assets		Liabilities
Energy related commodity contracts:
Derivatives – Energy Related – Current	$	33,826	$	37,979	$	24,242	$	23,828
Derivatives – Energy Related – Non-Current	14,642		25,563		12,297		5,403
Interest rate contracts:
Derivatives - Other - Non-Current	—		9,091		—		13,462
Total derivatives not designated as hedging instruments under GAAP	48,468		72,633		36,539		42,693
Total Derivatives	$	48,468	$	72,633	$	36,539	$	42,693

Offsetting assets and liabilities

As of June 30, 2013 and December 31, 2012, information related to these offsetting arrangements were as follows (in thousands):

As of June 30, 2013
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	48,468		$	—	$	48,468		$	(10,162	)	(A)	$	—	$	38,306
Derivatives - Energy Related Liabilities	$	(63,542	)	$	—	$	(63,542	)	$	10,162		(B)	$	24,078	$	(29,302	)
Derivatives - Other	$	(9,091	)	$	—	$	(9,091	)	$	—			$	—	$	(9,091	)

As of December 31, 2012
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	$	36,539		$	—	$	36,539		$	(12,975	)	(A)	$	—	$	23,564
Derivatives - Energy Related Liabilities	$	(29,231	)	$	—	$	(29,231	)	$	12,975		(B)	$	6,347	$	(9,909	)
Derivatives - Other	$	(13,462	)	$	—	$	(13,462	)	$	—			$	—	$	(13,462	)

(A) The balances at June 30, 2013 and December 31, 2012 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at June 30, 2013 and December 31, 2012 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, 2013 and 2012 are as follows (in thousands):

	Three Months Ended June 30,						Six Months Ended June 30,
Derivatives in Cash Flow Hedging Relationships	2013			2012			2013			2012
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$	—		$	(888	)	$	—		$	(752	)
Losses reclassified from AOCL into income (a)	$	(112	)	$	(183	)	$	(224	)	$	(370	)
Gains (losses) recognized in income on ineffective portion (a)	—			—			—			—

(a) Included in Interest Charges

	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments under GAAP	2013			2012		2013			2012
(Losses) gains on energy related commodity contracts (a)	$	(16,722	)	$	3,308	$	(23,771	)	$	10,279
Gains on interest rate contracts (b)	1,250			84		1,775			220
Total	$	(15,472	)	$	3,392	$	(21,996	)	$	10,499

(a)  Included in Operating Revenues - Non Utility

(b)  Included in Interest Charges

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RATES AND REGULATORY ACTIONS (Details) (USD $) In Millions, unless otherwise specified	1 Months Ended
	Jun. 30, 2013	May 31, 2013	Feb. 28, 2013	Jan. 31, 2013	Oct. 31, 2012	Jul. 31, 2012
Public Utilities, General Disclosures [Abstract]
Cost requested to be recovered through EEP I, approved additional investment				$ 2.5
Cost requested to be recovered through EEP, revenue increase	24.0
BGSS refunds made to customers				9.4
Investment requested to be recovered through CIRT III, term of AIRP			4 years			5 years
Investment requested to be recovered through CIRT III, amount of AIRP			141.2			250.0
Investment requested to be recovered through CIRT III, annual amount of AIRP			35.3			50.0
Petition to adjust BGSS and CIP, revenue decrease		17.9
Investment requested to be recovered through CIRT, revenue increase		15.5			13.2
Investment requested to be recovered through CIRT, investments to be rolled into base rate		6.9			110.6
CIRT investments		117.5
Costs requested for deferral, storm related	$ 0.7

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES:

GUARANTEES — The Company has recorded a liability of $0.3 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, 2013 for the fair value of the following guarantees:

In April 2007, SJI guaranteed certain obligations of LVE Energy Partners, LLC (LVE), an unconsolidated joint venture in which Marina has a 50% equity interest.  LVE entered into a 25-year contract with a resort developer to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.  LVE began construction of the facility in 2007 and expected to provide full energy service in 2010 when the resort was originally scheduled to be completed.  LVE suspended construction of the district energy system and central energy center in January 2009 after the resort developer’s announcement that it was delaying the completion of construction of the resort.

In March 2013, the resort developer purchased substantially all of the assets of LVE. As a result, the guarantees provided by SJI of certain performance obligations of LVE under the operating agreements between LVE and the resort developer were canceled.

During the six months ended June 30, 2013, the Company received $57.6 million of repayments of advances from LVE. As of June 30, 2013, the Company had remaining unsecured Notes Receivable - Affiliate of approximately $7.0 million due from LVE on the condensed consolidated balance sheets related to this project. During 2013, SJI provided support to LVE of approximately $1.8 million to cover interest and other project related costs.

As a result of the sale of substantially all of the assets, management has evaluated the investment in LVE and concluded that the fair value of this investment continues to be in excess of the carrying value as of June 30, 2013.

SJI and its joint venture partner have guaranteed the repayment of interest rate derivative contracts held by LVE which mature in November 2013. As of June 30, 2013 the amount required to satisfy these contracts is approximately $3.2 million. LVE is expected to have sufficient resources to satisfy these interest rate derivative contracts upon the liquidation of its remaining assets. 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 this guarantee.

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 February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 20 year contract with a developer to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012 and as a result, ACR is providing full energy services to the complex. Marina and its joint venture partner have agreed to provide a $5.0 million letter of credit to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI to or on behalf of ACR.

In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, of 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 is expected to be completed during the second half of 2013. Marina and its joint venture partner are obligated to make capital contributions to UMM, through Energenic, totaling approximately $10.0 million. In addition, SJI has guaranteed certain obligations of UMM under the operating and lease agreements between UMM and the university, for the terms of the agreements, commencing with the first year of operations. SJI has guaranteed up to $2.2 million for the first year. This amount is adjusted each year based upon the Consumer Price Index. SJI has also guaranteed certain construction obligations of UMM during the construction period, the majority of which are supported by a surety bond. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.

As of June 30, 2013, SJI had issued $5.1 million of guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.

COLLECTIVE BARGAINING AGREEMENTS— Unionized personnel represent approximately 45.0% of our workforce at June 30, 2013. 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 employees represented by the IBEW operate under a collective bargaining agreement that runs through February 28, 2017. SJESP employees represented by the IBEW operate under a collective bargaining agreement that runs through February 28, 2014. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that expire in August 2014.

STANDBY LETTERS OF CREDIT — As of June 30, 2013, SJI provided $27.6 million of standby letters of credit through SJI’s revolving credit facility to enable SJE to market retail electricity and for various construction activities. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.  

PENDING LITIGATION — The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.2 million related to all claims in the aggregate as of both June 30, 2013 and December 31, 2012. 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, 2012 as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012.

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RATES AND REGULATORY ACTIONS

6 Months Ended

Jun. 30, 2013

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 2013, the BPU approved an extension of the Company's Energy Efficiency Program (“EEP”) to June 30, 2013 and approved additional investments of up to $2.5 million. In June 2013, the BPU approved a further extension of SJG's EEP through June 2015 and authorized incremental investments totaling $24.0 million. The costs and returns associated with the EEP program investments will continue to be recovered through the Company's Energy Efficiency Tracker (“EET”).

Also in June 2013, SJG filed its annual EET petition requesting additional revenues to recover the costs of, and its allowed return on, prior investments associated with the EEP programs. This petition is currently pending.

In January 2013, SJG credited the accounts of SJG's periodic Basic Gas Supply Service (BGSS) customers with refunds totaling $9.4 million due to gas costs that were lower than projected.

In July 2012, SJG filed a petition to implement a five-year, $250.0 million Accelerated Infrastructure Replacement Program (“AIRP”). SJG proposed spending an incremental $50.0 million per year on the accelerated replacement of its cast iron and bare steel main and service infrastructure and was seeking a return on program investments as it had under prior Capital Investment Recovery Tracker ("CIRT") programs. SJG's CIRT III program expired on December 31, 2012. In February 2013, the parties executed a Stipulation agreeing to $35.3 million per year of incremental capital spending for four years, totaling $141.2 million under the AIRP. The BPU approved the Stipulation in February 2013.

In March 2013, SJG filed a joint petition with another utility requesting modifications to, and the continuation of, the Conservation Incentive Plan (“CIP”) program effective October 1, 2013. This petition is currently pending.

In May 2013, SJG made its annual BGSS and CIP filing requesting a $17.9 million decrease in annual revenues. This petition is currently pending.

In October 2012 SJG filed a petition requesting a $13.2 million increase in annual revenues by rolling $110.6 million of CIRT I, II and III investments into base rates. In May 2013, SJG filed a supplemental petition requesting to roll an additional $6.9 million of CIRT III investments into base rates, for a total annual revenue increase of $15.5 million related to $117.5 millionof CIRT investments made since our last base rate case in 2010. This petition is currently pending.

In June 2013, SJG filed a petition requesting deferral of incremental operating and maintenance expenses incurred due to Superstorm Sandy. These costs totaled $0.7 million and are expected to be recovered in SJG's next base rate case. This petition is currently pending.

There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2012. See Note 10 to the Consolidated Financial Statements in Item 8 of SJI's Annual Report on Form 10-K as of December 31, 2012.

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STOCK-BASED COMPENSATION PLAN

6 Months Ended

Jun. 30, 2013

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

STOCK-BASED COMPENSATION PLAN

STOCK-BASED COMPENSATION PLAN:

Under the Amended and Restated 1997 Stock-Based Compensation Plan, no more than 2,000,000 shares in the aggregate may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. The plan will terminate on January 26, 2015, unless terminated earlier by the Board of Directors. No options were granted or outstanding during the six months ended June 30, 2013 and 2012.  No stock appreciation rights have been issued under the plan. During the six months ended June 30, 2013 and 2012, SJI granted 56,464 and 40,955 restricted shares to Officers and other key employees, respectively.  These restricted shares vest over a three-year period and are subject to SJI achieving certain market and earnings-based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 150% of the original share units granted. Grants containing market-based performance targets have been issued in each of the last three years and use SJI's total shareholder return (TSR) relative to a peer group to measure performance. Beginning with 2012, grants containing earnings-based targets have also been issued. These new grants are based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance. During the six months ended June 30, 2013 and 2012, SJI granted 12,285 and 9,904 restricted shares, respectively, to Directors.  Shares issued to Directors in 2011 vest over a three-year service period and contain no performance conditions. Shares issued to Directors in 2012 and 2013 vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest.

See Note 2 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2012 for the related accounting policy.

The following table summarizes the nonvested restricted stock awards outstanding at June 30, 2013 and the assumptions used to estimate the fair value of the awards:

	Grant Date	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Officers & Key Employees -	Jan. 2011 - TSR	40,069	$	50.940	27.5	%	1.01	%
	Jan. 2012 - TSR	20,090	$	51.230	22.5	%	0.43	%
	Jan. 2012 - EPS	20,090	$	56.930	N/A		N/A
	Jan. 2013 - TSR	27,763	$	44.380	21.1	%	0.40	%
	Jan. 2013 - EPS	27,763	$	51.180	N/A		N/A
Directors -	Jan. 2011	7,332	$	52.940	—		—
	Jan. 2013	12,285	$	51.740	—		—

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, 2013 and 2012 (in thousands):

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Officers & Key Employees	$	566		$	524		$	1,139		$	1,048
Directors	191			228			382			354
Total Cost	757			752			1,521			1,402
Capitalized	(63		)	(58		)	(126		)	(115		)
Net Expense	$	694		$	694		$	1,395		$	1,287

As of June 30, 2013, there was $4.0 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the restricted stock plans. That cost is expected to be recognized over a weighted average period of 1.9 years.

The following table summarizes information regarding restricted stock award activity during the six months ended June 30, 2013, excluding accrued dividend equivalents:

	Officers &Other Key Employees		Directors		Weighted Average Fair Value
Nonvested Shares Outstanding, January 1, 2013	81,005		27,688		$	51.292
Granted	56,464		12,285		$	48.488
Cancelled/Forfeited	(1,694	)	—		$	50.302
Vested	—		(20,356	)	$	45.809
Nonvested Shares Outstanding, June 30, 2013	135,775		19,617		$	50.780

During the six months ended June 30, 2013 and 2012, SJI awarded 66,077 shares to its Officers and other key employees, which had vested at December 31, 2012, at a market value of $3.3 million, and 33,322 shares, which had vested at December 31, 2011, at a market value of $1.9 million, respectively. Also, during the six months ended June 30, 2013 and 2012, SJI awarded 12,285 and 9,904 shares to its Directors at a market value of $0.6 million for each period. The Company has a policy of issuing new shares to satisfy its obligations under these plans; therefore, there are no cash payment requirements resulting from the normal operation of these plans. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash.  At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods.  These deferred shares are included in Treasury Stock on the condensed consolidated balance sheets.

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended			6 Months Ended
	Jun. 30, 2013		Jun. 30, 2012	Jun. 30, 2013		Jun. 30, 2012	Jun. 30, 2013 Fair Value, Measurements, Recurring [Member] Total [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Total [Member]		Jun. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 1 [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 1 [Member]		Jun. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 2 [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 2 [Member]		Jun. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 3 [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 3 [Member]
Assets [Abstract]
Available-for-Sale Securities							$ 7,859	[1]	$ 7,538	[1]	$ 7,859	[1]	$ 787	[1]	$ 0	[1]	$ 6,751	[1]	$ 0	[1]	$ 0	[1]
Derivatives - Energy Related Assets							48,468	[2]	36,539	[2]	6,444	[2]	9,404	[2]	17,811	[2]	16,205	[2]	24,213	[2]	10,930	[2]
Total Assets							56,327		44,077		14,303		10,191		17,811		22,956		24,213		10,930
Liabilities [Abstract]
Derivatives - Energy Related Liabilities							63,542	[2]	29,231	[2]	4,065	[2]	5,399	[2]	26,749	[2]	15,664	[2]	32,728	[2]	8,168	[2]
Derivatives - Other							9,091	[3]	13,462	[3]	0	[3]	0	[3]	9,091	[3]	13,462	[3]	0	[3]	0	[3]
Total Liabilities							72,633		42,693		4,065		5,399		35,840		29,126		32,728		8,168
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period	1,627		(1,958)	2,762		(5,958)
Total (losses) gains realized/unrealized included in earnings	(12,022)		3,306	(12,723)		3,475
Transfers in/(out) of Level 3	928	[4]		928	[4]
Settlements	952		1,730	518		5,561
Balance at end of period	$ (8,515)		$ 3,078	$ (8,515)		$ 3,078

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

[2] Derivatives – 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 are 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 are fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.

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

[4] Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the three and six months ended June 30, 2013, $0.9 million of net derivatives assets were transferred from Level 2 to Level 3, due to decreased observability of market data. The transfer was recognized as of the end of the second quarter.

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COMMITMENTS AND CONTINGENCIES (Details) (USD $)						1 Months Ended			1 Months Ended				1 Months Ended	6 Months Ended
	Jun. 30, 2013 unions sites	Dec. 31, 2012	Jun. 30, 2013 Letter of Credit, Developer [Member]	Jun. 30, 2013 Standby Letter of Credit [Member]	Jun. 30, 2013 Letter of Credit, Separate Facility [Member]	Feb. 28, 2011 ACR Energy Partners LLC [Member]	Jun. 30, 2013 ACR Energy Partners LLC [Member]	Jun. 30, 2013 Energenic [Member]	May 31, 2012 Energenic [Member] UMM Energy Partners, LLC [Member]	May 31, 2012 Energenic [Member] UMM Energy Partners, LLC [Member] Maximum [Member]	Jun. 30, 2013 Parental Guarantee [Member]	Jun. 30, 2013 LVE Energy Partners, LLC (LVE) [Member]	Apr. 30, 2007 Marina Energy LLC [Member] LVE Energy Partners, LLC (LVE) [Member]	Jun. 30, 2013 Marina Energy LLC [Member] LVE Energy Partners, LLC (LVE) [Member] LVE Energy Partners [Member]
Guarantees [Abstract]
Liability recorded related to guarantees	$ 300,000
Equity interest (in hundredths)							50.00%	50.00%				50.00%	50.00%
Contract with a resort developer (in years)						20 years							25 years
Proceeds from Divestiture of Interest in Joint Venture														57,600,000
Notes receivable - affiliate	5,287,000	39,495,000												7,000,000
Maximum capital risk														1,800,000
Maximum amount of obligation under guarantee contracts	4,200,000													3,200,000
Letter of credit provided	660,000,000		5,000,000	27,600,000	87,600,000
Guaranteed amount											5,100,000
Contract term									30 years
Capital contribution obligation, joint venture									10,000,000
Annual obligations under the agreement										2,200,000
Collective bargaining agreements [Abstract]
Percentage of personnel represented by collective bargaining agreements (in hundredths)	45.00%
Number of unions (in unions)	2
Pending litigation [Abstract]
Estimated litigation liability	$ 3,200,000	$ 3,200,000
Environmental remediation costs [Abstract]
Number of sites for environmental cleanup (in number of sites)	12

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Accounting Policies [Abstract]
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales	$ 700,000	$ 900,000	$ 2,900,000	$ 3,400,000
Decrease in TEFA revenue based tax rate	25.00%		25.00%		25.00%
Impairment charges			0	1,100,000
Amount of costs related to interests in proved and unproved properties in Pennsylvania, net of amortization	$ 9,000,000		$ 9,000,000		$ 9,000,000
Shares of treasury stock held (in shares)	134,783		134,783		145,414

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LONG-TERM DEBT

6 Months Ended

Jun. 30, 2013

Long-term Debt, Unclassified [Abstract]

LONG-TERM DEBT

LONG-TERM DEBT:

In 2011, SJG received approval from the BPU to issue up to $200.0 million in long-term debt under its Medium Term Note program by September 2014. At June 30, 2013, $80.0 million was available under this program.

In February 2012, SJG called its $35.0 million, 7.70% Medium Term Notes due April 2027 at par plus a 2.0% premium. The early redemption occurred concurrently with the issuance in April 2012 of $35.0 million, 3.74% Series D Medium Term Notes due April 2032.

The Company did not issue or retire any long-term debt during the six months ended June 30, 2013.

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UNUSED LINES OF CREDIT

6 Months Ended

Jun. 30, 2013

Line of Credit Facility [Abstract]

UNUSED LINES OF CREDIT

UNUSED LINES OF CREDIT:

Credit facilities and available liquidity as of June 30, 2013 were as follows (in thousands):

Company	Total Facility		Usage		Available Liquidity		Expiration Date
SJG:
Commercial Paper Program/Revolving Credit Facility	$	200,000	$	93,000	$	107,000	May 2015
Uncommitted Bank Lines (B)	10,000		—		10,000		August 2013
Total SJG	210,000		93,000		117,000
SJI:
Revolving Credit Facility	$	400,000	$	180,300	$	219,700	February 2018 (A)
Term Line of Credit	50,000		50,000		—		November 2013
Total SJI	450,000		230,300		219,700
Total	$	660,000	$	323,300	$	336,700

(A) Includes letters of credit outstanding in the amount of $27.6 million.

(B) Although there can be no assurances, SJG anticipates renewing the remaining line of credit during the third quarter 2013.

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 0.98% and 0.95% at June 30, 2013 and 2012, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2013 and 2012 were $275.3 million and $376.2 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2013 and 2012 were $369.5 million and $462.2 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, 2013.

SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million.  The notes  have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes.  SJG uses the commercial paper program in tandem with the $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Jun. 30, 2013

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.

▪ Marina Energy, LLC (Marina) develops and operates on-site energy-related projects.

▪ 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 Energy Service Plus, LLC (SJESP) services residential and 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, and the installation of small commercial HVAC systems.

▪ South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.

BASIS OF PRESENTATION

BASIS OF PRESENTATION — The condensed consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which we have a controlling interest. We eliminate 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 2012 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.

Certain reclassifications have been made to the prior period segment disclosures to conform to the current period presentation. In all periods presented, net receivables between the Discontinued Operations segment and the Corporate and Services segment have been reclassified in the Identifiable Assets Segment disclosure in Note 6.

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). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both utility revenue and cost of sales and totaled $0.7 million and $0.9 million for the three months ended June 30, 2013 and 2012, respectively, and $2.9 million and $3.4 million for the six months ended June 30, 2013 and 2012, respectively. The TEFA is subject to a planned phase-out which decreases the assessment in increments of 25% in 2012 and 2013 and is eliminated after December 31, 2013.

GAS EXPLORATION AND DEVELOPMENT

GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. No impairment was recorded during the six months ended June 30, 2013. During the six months ended June 30, 2012, the Company recorded $1.1 million of impairment charges within Other Income and Expense on the condensed consolidated statement of income due to a reduction in the expected cash flows to be received from certain shallow wells in the Marcellus region. As of both June 30, 2013 and December 31, 2012, $9.0 million related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with Nonutility Property and Equipment and Other Noncurrent Assets on the condensed consolidated balance sheets.

TREASURY STOCK

TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of June 30, 2013 and December 31, 2012, SJI held 134,783 and 145,414 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI.

INCOME TAXES

INCOME TAXES — Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 740 - “Income Taxes”.  A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of the non-regulated entities 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 2013 and 2012 had, or is expected to have, a material impact on the condensed consolidated financial statements.

In January 2012, the FASB issued Accounting Standards Update (ASU) 2011-11, Enhanced Disclosure Requirements Concerning Offsetting of Financial Assets and Financial Liabilities. This ASU amends ASC 210-20 to add disclosure requirements in respect of the offsetting of financial assets and financial liabilities. In February 2013, the FASB issued ASU 2013-01 Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which amends and clarifies the scope of the balance sheet offsetting disclosures required through ASU 2011-11. The new guidance is effective for fiscal years beginning on or after January 1, 2013. The adoption of this guidance modified the disclosures around derivative instruments, but did not have an impact on the Company's financial statement results.

In February 2013, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.

FAIR VALUE

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

(B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable.

Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are 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 are 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.

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ACCUMULATED OTHER COMPREHENSIVE LOSS

6 Months Ended

Jun. 30, 2013

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, 2013 (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, 2013 (a)	$	(23,437	)	$	(2,896	)	$	20		$	14	$	(26,299	)
Other comprehensive income before reclassifications	—			—			(23		)	—		(23		)
Amounts reclassified from AOCL (b)	—			66			—			22		88
Net current period other comprehensive income (loss)	—			66			(23		)	22		65
Balance at June 30, 2013 (a)	$	(23,437	)	$	(2,830	)	$	(3	)	$	36	$	(26,234	)

	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, 2013 (a)	$	(23,437	)	$	(2,962	)	$	294		$	(5,000	)	$	(31,105	)
Other comprehensive income before reclassifications	—			—			192			—			192
Amounts reclassified from AOCL (b)	—			132			(489		)	5,036			4,679
Net current period other comprehensive income (loss)	—			132			(297		)	5,036			4,871
Balance at June 30, 2013 (a)	$	(23,437	)	$	(2,830	)	$	(3	)	$	36		$	(26,234	)

(a) Determined using a combined statutory tax rate of 41%.

(b) See table below.

The following table provides details about reclassifications out of AOCL for the three and six months ended June 30, 2013:

	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Consolidated Statements of Income
	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	112		$	224		Interest Charges
Income Taxes	(46		)	(92		)	Income Taxes (a)
	$	66		$	132
Unrealized Gain on Available-for-Sale Securities	$	—		$	(827	)	Other Income
Income Taxes	—			338			Income Taxes (a)
	$	—		$	(489	)
Loss of Affiliated Companies	$	35		$	8,511		Equity in Loss of Affiliated Companies
Income Taxes	(13		)	(3,475		)	Income Taxes (a)
	$	22		$	5,036
Losses from reclassifications for the period net of tax	$	88		$	4,679

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Document and Entity Information Document	6 Months Ended
	Jun. 30, 2013	Aug. 01, 2013
Entity Information [Line Items]
Entity Registrant Name	SOUTH JERSEY INDUSTRIES INC
Entity Central Index Key	0000091928
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		31,984,745

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SUBSEQUENT EVENT

6 Months Ended

Jun. 30, 2013

Subsequent Events [Abstract]

SUBSEQUENT EVENT

SUBSEQUENT EVENT:

In July 2013, SJG redeemed at par $10.5 million of 4.46% Medium Term Notes issued in July 2003.