Edgar Filing: SOUTH JERSEY INDUSTRIES INC

SJI-6.30.14-10Q

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, 2014



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, 2014 there were 33,135,306 shares of the registrant’s common stock outstanding.

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		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. 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
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	47
Item 4.	Controls and Procedures	49

PART II	OTHER INFORMATION

Item 1.	Legal Proceedings	50
Item 1A.	Risk Factors	50
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	X
Item 6.	Exhibits	50

Signatures		51

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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,
	2014			2013
Operating Revenues:
Utility	$	68,903		$	66,040
Nonutility	64,368			56,552
Total Operating Revenues	133,271			122,592
Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility	24,623			25,611
- Nonutility	54,324			62,216
Operations	30,652			27,957
Maintenance	3,181			3,365
Depreciation	15,495			12,372
Energy and Other Taxes	1,241			1,664
Total Operating Expenses	129,516			133,185
Operating Income (Loss)	3,755			(10,593		)

Other Income and Expense	4,185			2,665
Interest Charges	(6,846		)	(3,420		)
Income (Loss) Before Income Taxes	1,094			(11,348		)
Income Taxes	9,510			11,632
Equity in (Loss) Earnings of Affiliated Companies	(903		)	632
Income from Continuing Operations	9,701			916
Loss from Discontinued Operations - (Net of tax benefit)	(80		)	(28		)
Net Income	$	9,621		$	888

Basic Earnings Per Common Share:
Continuing Operations	$	0.29		$	0.03
Discontinued Operations	—			—
Basic Earnings Per Common Share	$	0.29		$	0.03

Average Shares of Common Stock Outstanding - Basic	32,963			31,949

Diluted Earnings Per Common Share:
Continuing Operations	$	0.29		$	0.03
Discontinued Operations	—			—
Diluted Earnings Per Common Share	$	0.29		$	0.03

Average Shares of Common Stock Outstanding - Diluted	33,037			32,012

Dividends Declared Per Common Share	$	0.47		$	0.44

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

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	Six Months Ended June 30,
	2014			2013
Operating Revenues:
Utility	$	279,232		$	239,691
Nonutility	204,240			138,531
Total Operating Revenues	483,472			378,222
Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility	127,700			102,766
- Nonutility	179,385			137,361
Operations	70,002			60,646
Maintenance	6,440			6,787
Depreciation	30,486			23,779
Energy and Other Taxes	3,194			5,497
Total Operating Expenses	417,207			336,836
Operating Income	66,265			41,386

Other Income and Expense	6,553			6,534
Interest Charges	(13,930		)	(8,128		)
Income Before Income Taxes	58,888			39,792
Income Tax (Expense) Benefit	(2,359		)	3,860
Equity in Earnings of Affiliated Companies	1,383			601
Income from Continuing Operations	57,912			44,253
Loss from Discontinued Operations - (Net of tax benefit)	(393		)	(499		)
Net Income	$	57,519		$	43,754

Basic Earnings Per Common Share:
Continuing Operations	$	1.76		$	1.39
Discontinued Operations	(0.01		)	(0.02		)
Basic Earnings Per Common Share	$	1.75		$	1.37

Average Shares of Common Stock Outstanding - Basic	32,864			31,853

Diluted Earnings Per Common Share:
Continuing Operations	$	1.76		$	1.39
Discontinued Operations	(0.01		)	(0.02		)
Diluted Earnings Per Common Share	$	1.75		$	1.37

Average Shares of Common Stock Outstanding - Diluted	32,940			31,912

Dividends Declared per Common Share	$	0.94		$	0.89

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

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SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(In Thousands)



	Three Months Ended June 30,
	2014			2013
Net Income	$	9,621		$	888

Other Comprehensive Income, Net of Tax:*

Unrealized Gain (Loss) on Available-for-Sale Securities	154			(23		)
Unrealized Gain on Derivatives - Other	66			66
Other Comprehensive (Loss) Income of Affiliated Companies	(82		)	22

Other Comprehensive Income - Net of Tax*	138			65

Comprehensive Income	$	9,759		$	953




	Six Months Ended June 30,
	2014			2013
Net Income	$	57,519		$	43,754

Other Comprehensive Income, Net of Tax:*

Unrealized Gain (Loss) on Available-for-Sale Securities	216			(297		)
Unrealized Gain on Derivatives - Other	132			132
Other Comprehensive (Loss) Income of Affiliated Companies	(100		)	5,036

Other Comprehensive Income - Net of Tax*	248			4,871

Comprehensive Income	$	57,767		$	48,625

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

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

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SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(In Thousands)



	Six Months Ended June 30,
	2014			2013
Net Cash Provided by Operating Activities	$	89,669		$	62,509

Cash Flows from Investing Activities:
Capital Expenditures	(134,945		)	(88,305		)
Net Proceeds from Sale of (Purchase of) Restricted Investments in Margin Account	3,333			(13,840		)
Purchase of Restricted Investments with Escrowed Loan Proceeds	—			(40		)
Investment in Long-Term Receivables	(3,410		)	(3,256		)
Proceeds from Long-Term Receivables	3,536			3,433
Purchase of Company Owned Life Insurance	(526		)	(3,785		)
Investment in Affiliate	—			(2,492		)
Advances on Notes Receivable - Affiliate	(1,922		)	(6,157		)
Repayment of Notes Receivable - Affiliate	5,639			94,360

Net Cash Used in Investing Activities	(128,295		)	(20,082		)

Cash Flows from Financing Activities:
Net Repayments of Short-Term Credit Facilities	(147,200		)	(43,200		)
Proceeds from Issuance of Long-Term Debt	189,000			—
Payments for Issuance of Long-Term Debt	(1,204		)	(5		)
Dividends on Common Stock	(15,510		)	(14,102		)
Proceeds from Sale of Common Stock	17,119			12,502

Net Cash Provided by (Used in) Financing Activities	42,205			(44,805		)

Net Increase (Decrease) in Cash and Cash Equivalents	3,579			(2,378		)
Cash and Cash Equivalents at Beginning of Period	3,818			4,638

Cash and Cash Equivalents at End of Period	$	7,397		$	2,260

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

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SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

(In Thousands)



	June 30, 2014			December 31, 2013
Assets
Property, Plant and Equipment:
Utility Plant, at original cost	$	1,902,141		$	1,816,804
Accumulated Depreciation	(405,013		)	(392,029		)
Nonutility Property and Equipment, at cost	512,648			486,332
Accumulated Depreciation	(64,329		)	(52,009		)

Property, Plant and Equipment - Net	1,945,447			1,859,098

Investments:
Available-for-Sale Securities	9,114			8,716
Restricted	39,782			43,115
Investment in Affiliates	78,421			78,273

Total Investments	127,317			130,104

Current Assets:
Cash and Cash Equivalents	7,397			3,818
Accounts Receivable	284,231			253,566
Unbilled Revenues	17,929			47,594
Provision for Uncollectibles	(6,516		)	(5,854		)
Notes Receivable - Affiliate	6,339			8,908
Natural Gas in Storage, average cost	33,195			57,786
Materials and Supplies, average cost	2,804			2,798
Deferred Income Taxes - Net	26,970			30,609
Prepaid Taxes	23,849			9,431
Derivatives - Energy Related Assets	58,213			56,327
Other Prepayments and Current Assets	20,365			17,915

Total Current Assets	474,776			482,898

Regulatory and Other Noncurrent Assets:
Regulatory Assets	314,725			296,081
Derivatives - Energy Related Assets	13,106			26,451
Unamortized Debt Issuance Costs	9,472			7,803
Notes Receivable-Affiliate	38,977			39,907
Contract Receivables	14,354			14,595
Notes Receivable	7,882			7,882
Other	60,482			60,036

Total Regulatory and Other Noncurrent Assets	458,998			452,755

Total Assets	$	3,006,538		$	2,924,855

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

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SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

(In Thousands)



	June 30, 2014			December 31, 2013
Capitalization and Liabilities
Equity:
Common Stock	$	41,300		$	40,894
Premium on Common Stock	418,829			401,011
Treasury Stock (at par)	(161		)	(186		)
Accumulated Other Comprehensive Loss	(20,512		)	(20,760		)
Retained Earnings	432,438			406,041

Total Equity	871,894			827,000

Long-Term Debt	805,400			680,400

Total Capitalization	1,677,294			1,507,400

Current Liabilities:
Notes Payable	206,700			353,900
Current Portion of Long-Term Debt	85,000			21,000
Accounts Payable	242,710			259,757
Customer Deposits and Credit Balances	17,434			15,546
Environmental Remediation Costs	23,715			16,695
Taxes Accrued	2,411			3,234
Derivatives - Energy Related Liabilities	93,123			77,993
Dividends Payable	15,611			—
Interest Accrued	6,861			6,363
Pension Benefits	1,241			1,275
Other Current Liabilities	6,608			9,210

Total Current Liabilities	701,414			764,973

Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	318,100			319,368
Investment Tax Credits	254			360
Pension and Other Postretirement Benefits	60,297			57,370
Environmental Remediation Costs	96,275			106,734
Asset Retirement Obligations	42,225			41,687
Derivatives - Energy Related Liabilities	17,247			22,131
Derivatives - Other	8,740			6,676
Regulatory Liabilities	49,792			60,949
Finance Obligation	20,163			20,656
Other	14,737			16,551

Total Deferred Credits and Other Noncurrent Liabilities	627,830			652,482

Commitments and Contingencies (Note 11)

Total Capitalization and Liabilities	$	3,006,538		$	2,924,855

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

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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.


▪	South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets on a wholesale basis in the mid-Atlantic, Appalachian and southern states.


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


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


▪	South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.

BASIS OF PRESENTATION — The condensed consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management’s opinion, the condensed consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI’s financial position, operating results and cash flows at the dates and for the periods presented. SJI’s businesses are subject to seasonal fluctuations and, accordingly, this interim financial information should not be the basis for estimating the full year’s operating results. As permitted by the rules and regulations of the Securities and Exchange Commission (SEC), the accompanying unaudited condensed consolidated financial statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These financial statements should be read in conjunction with SJI’s 2013 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.

Certain reclassifications have been made to the prior periods regulatory assets disclosure to conform to the current period presentation. The deferred pipeline integrity cost and Allowance for Funds Used During Construction ("AFUDC") - equity related deferrals previously included in "Other Regulatory Assets" were reclassified to the line items "Pipeline Integrity Cost" and "AFUDC - Equity Related Deferrals", respectively, in the regulatory asset table in Note 8.

REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. The PUA is included in both utility revenue and cost of sales and totaled $0.2 million and $0.7 million for the three months ended June 30, 2014 and 2013, respectively, and $0.6 million and $2.9 million for the six months ended June 30, 2014 and 2013, respectively. In prior years, SJG had collected a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). The TEFA was eliminated effective January 1, 2014.

IMPAIRMENT OF LONG-LIVED ASSETS - SJI reviews the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the six months ended June 30, 2014 and 2013, no impairments were identified.

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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, 2014 or 2013. As of June 30, 2014 and December 31, 2013, $8.8 million and $8.9 million, respectively, 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, 2014 and December 31, 2013, SJI held 128,979 and 148,890 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI.

INCOME TAXES — Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 740 - “Income Taxes”. A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of Marina are recognized on the flow through method, which may result in variations in the customary relationship between income taxes and pre-tax income for interim periods.

NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2014 or 2013 had, or is expected to have, a material impact on the condensed consolidated financial statements.

In July 2013, the FASB issued Accounting Standards Update (ASU) 2013-11, Balance Sheet Presentation of an Unrecognized Income Tax Benefit for a Net Operating Loss or Tax Credit Carryforward. This ASU provides that a liability related to an unrecognized tax benefit should be offset against a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance did not have an impact on the Company's financial statement results.

In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606), This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.


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, 2014 and 2013. No stock appreciation rights have been issued under the plan. During the six months ended June 30, 2014 and 2013, SJI granted 68,453 and 56,464 restricted shares, respectively, to Officers and other key employees. These restricted shares vest over a three-year period and are subject to SJI achieving certain market and earnings-based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 150% of the original share units granted.

Grants containing market-based performance targets use SJI's total shareholder return (TSR) relative to a peer group to measure performance. Grants containing earnings-based targets are based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance.

During the six months ended June 30, 2014 and 2013, SJI granted 11,610 and 12,285 restricted shares, respectively, to Directors. Shares issued to Directors vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest.

See Note 2 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013 for the related accounting policy.

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The following table summarizes the nonvested restricted stock awards outstanding at June 30, 2014 and the assumptions used to estimate the fair value of the awards:



	Grant Date	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Officers & Key Employees -	Jan. 2012 - TSR	18,268	$	51.23	22.5	%	0.43	%
	Jan. 2012 - EPS	18,268	$	56.93	N/A		N/A
	Jan. 2013 - TSR	24,797	$	44.38	21.1	%	0.40	%
	Jan. 2013 - EPS	24,797	$	51.18	N/A		N/A
	Jan. 2014 - TSR	31,267	$	44.32	20.0	%	0.80	%
	Jan. 2014 - EPS	31,267	$	54.44	N/A		N/A

Directors -	Jan. 2014	11,610	$	54.51	N/A		N/A

Expected volatility is based on the actual volatility of SJI’s share price over the preceding three-year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three-year term of the Officers’ and other key employees’ restricted shares. As notional dividend equivalents are credited to the holders during the three-year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant.

The following table summarizes the total stock-based compensation cost for the three and six months ended June 30, 2014 and 2013 (in thousands):



	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
Officers & Key Employees	$	586		$	566		$	1,167		$	1,139
Directors	158			191			316			382
Total Cost	744			757			1,483			1,521

Capitalized	(70		)	(63		)	(140		)	(126		)
Net Expense	$	674		$	694		$	1,343		$	1,395

As of June 30, 2014, there was $4.3 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, 2014, excluding accrued dividend equivalents:



	Officers &Other Key Employees		Directors		Weighted Average Fair Value
Nonvested Shares Outstanding, January 1, 2014	94,192		19,617		$	50.73
Granted	68,453		11,610		$	50.12
Cancelled/Forfeited	(13,981	)	—		$	49.85
Vested	—		(19,617	)	$	52.19
Nonvested Shares Outstanding, June 30, 2014	148,664		11,610		$	50.33

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Performance targets during the three-year vesting period were not attained for the January 2011 grant that had vested at December 31, 2013. As a result, no shares were awarded in 2014. During the six months ended June 30, 2013, SJI awarded 66,077 shares to its Officers and other key employees, which had vested at December 31, 2012, at a market value of $3.3 million. Also, during the six months ended June 30, 2014 and 2013, SJI granted 11,610 and 12,285 shares to its Directors at a market value of $0.6 million for each period. The Company has a policy of issuing new shares to satisfy its obligations under these plans; therefore, there are no cash payment requirements resulting from the normal operation of these plans. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash. At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods. These deferred shares are included in Treasury Stock on the condensed consolidated balance sheets.


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,
	2014			2013			2014			2013
Loss Before Income Taxes:
Sand Mining	$	(103	)	$	(20	)	$	(483	)	$	(92	)
Fuel Oil	(20		)	(23		)	(122		)	(675		)
Income Tax Benefits	43			15			212			268
Loss from Discontinued Operations — Net	$	(80	)	$	(28	)	$	(393	)	$	(499	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic and Diluted	$	—		$	—		$	(0.01	)	$	(0.02	)

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 had a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.9 million in 2013. LVE was dissolved prior to December 31, 2013. See Note 11.

During the first six months of 2014, the Company received net repayments from unconsolidated affiliates of $3.7 million. During the first six months of 2013, the Company made investments in, and provided net advances to, unconsolidated affiliates of $7.3 million, excluding the cash proceeds related to the sale of LVE and the repayment of the advances to Energenic as discussed above. As of June 30, 2014 and December 31, 2013, the outstanding balance on these Notes Receivable – Affiliate was $45.3 million and $48.8 million, respectively. These notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025.

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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, 2014, the Company had a net asset of approximately $77.6 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, 2014 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $123.7 million plus the guarantees discussed in Note 11.


4.	COMMON STOCK:

The following shares were issued and outstanding:



	2014
Beginning Balance, January 1	32,715,042
New Issues During the Period:
Dividend Reinvestment Plan	313,522
Stock-Based Compensation Plan	11,610
Ending Balance, June 30	33,040,174

The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $17.8 million was recorded in Premium on Common Stock.

EARNINGS PER COMMON SHARE (EPS) — Basic EPS is based on the weighted-average number of common shares outstanding. The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 74,332 and 63,174 for the three months ended June 30, 2014 and 2013, respectively, and 75,778 and 58,374 for the six months ended June 30, 2014 and 2013, respectively. These shares relate to SJI's restricted stock as discussed in Note 2.

DIVIDEND REINVESTMENT PLAN (DRP) —The Company offers a DRP which allows participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases. Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $17.1 million and $12.5 million of equity capital through the DRP during the six months ended June 30, 2014 and 2013, 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, 2014 and December 31, 2013, the escrowed proceeds, including interest earned, totaled $1.4 million and $1.3 million, respectively.

The Company maintains margin accounts with selected counterparties to support its risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy-related contracts with the respective counterparties decrease. As of June 30, 2014 and December 31, 2013, the balances in these accounts totaled $38.4 million and $41.8 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at June 30, 2014 and December 31, 2013, which would be included in Level 1 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities).

LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources. The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest. The carrying amounts of such loans were $15.0 million as of both June 30, 2014 and December 31, 2013. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the condensed consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.3 million as of both June 30, 2014 and December 31, 2013. The annual amortization to interest is not material to the Company’s condensed consolidated financial statements. The carrying amounts of these receivables approximate their fair value at June 30, 2014 and December 31, 2013, which would be included in Level 2 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities).

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CREDIT RISK - As of June 30, 2014, approximately $25.6 million, or 35.9%, of the current and noncurrent Derivatives – Energy Related Assets are with two, investment-grade rated counterparties.

FINANCE OBLIGATION - During 2010, ACB Energy Partners LLC (ACB), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, completed construction of a combined heat and power generating facility to serve, under an energy services agreement, a thermal plant owned by Marina. Construction period financing was provided by Marina. As substantially all of the costs of constructing the facility were funded by the financing provided by Marina, Marina was considered the owner of the facility for accounting purposes during the construction period. When an entity is considered the accounting owner during the construction period, a sale of the asset effectively occurs when construction of the asset is completed. However, due to its continuing involvement in the facility through its equity interest in Energenic, Marina continues to be considered the owner of the facility for accounting purposes under ASC Topic 360 Property, Plant and Equipment. As a result, the transaction is being accounted for as a financing arrangement under ASC Topic 840 Leases and, therefore, the Company has included costs to construct the facility within Nonutility Property, Plant and Equipment on the condensed consolidated balance sheets of $23.7 million as of both June 30, 2014 and December 31, 2013. In addition, the Company included repayments from ACB to Marina on the construction loan within the Finance Obligation on the condensed consolidated balance sheets. Marina does not have a fixed payment obligation to ACB; as a result, the Finance Obligation is classified as a noncurrent liability on the condensed consolidated balance sheets. The costs to construct the facility and the repayments of the construction loan are amortized over the term of the energy services agreement related to the project. The impact on the condensed consolidated statements of income is not significant. As a result, the Company recorded $20.2 million and $20.7 million, net of amortization, within Finance Obligation on the condensed consolidated balance sheets at June 30, 2014 and December 31, 2013, respectively.

FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJI's financial instruments approximate their fair values at June 30, 2014 and December 31, 2013, except as noted below.

•

For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to SJI at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy, see Note 13 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJI's long-term debt, including current maturities, as of June 30, 2014 and December 31, 2013, were $932.2 million and $713.2 million, respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of June 30, 2014 and December 31, 2013, were $890.4 million and $701.4 million, respectively.

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6.	SEGMENTS OF BUSINESS:

SJI operates in several different reportable operating segments. These segments are as follows:


•	Gas utility operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers.


•	Wholesale energy operations include the activities of SJRG and SJEX.


•	SJE is involved in both retail gas and retail electric activities.


◦	Retail gas and other operations include natural gas acquisition and transportation service business lines.


◦	Retail electric operations consist of electricity acquisition and transportation to commercial and industrial customers.


•	On-site energy production consists of Marina's thermal energy facility and other energy-related projects.


•	Appliance service operations includes SJESP’s servicing of appliances under warranty via a subcontractor arrangement as well as on a time and materials basis.

In the first quarter of 2014, SJI began grouping its non-utility operations into two areas: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes on-site energy production and appliance service operations. Due to this grouping, some of the Company's prior period numbers were recast to conform with the current period presentation. However, no changes were made to the specific operating segments. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices.

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



	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
Operating Revenues:
Gas Utility Operations	$	69,159		$	66,536		$	279,704		$	240,634
Energy Group:
Wholesale Energy Operations	(2,936		)	(10,699		)	32,436			(4,482		)
Retail Gas and Other Operations	24,875			24,585			76,381			58,698
Retail Electric Operations	27,879			31,419			68,272			62,148
Subtotal Energy Group	49,818			45,305			177,089			116,364
Energy Services:
On-Site Energy Production	14,397			9,965			25,743			19,059
Appliance Service Operations	2,637			3,133			5,291			6,441
Subtotal Energy Services	17,034			13,098			31,034			25,500
Corporate & Services	6,452			7,362			14,323			15,842
Subtotal	142,463			132,301			502,150			398,340
Intersegment Sales	(9,192		)	(9,709		)	(18,678		)	(20,118		)
Total Operating Revenues	$	133,271		$	122,592		$	483,472		$	378,222

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	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
Operating Income (Loss):
Gas Utility Operations	$	9,005		$	8,069		$	72,445		$	65,864
Energy Group:
Wholesale Energy Operations	(8,468		)	(19,200		)	(10,123		)	(24,357		)
Retail Gas and Other Operations	(191		)	(160		)	1,777			(132		)
Retail Electric Operations	(840		)	(337		)	(894		)	127
Subtotal Energy Group	(9,499		)	(19,697		)	(9,240		)	(24,362		)
Energy Services:
On-Site Energy Production	3,636			268			2,376			(905		)
Appliance Service Operations	357			799			262			785
Subtotal Energy Services	3,993			1,067			2,638			(120		)
Corporate and Services	256			(32		)	422			4
Total Operating Income (Loss)	$	3,755		$	(10,593	)	$	66,265		$	41,386

Depreciation and Amortization:
Gas Utility Operations	$	12,757		$	12,929		$	25,433		$	23,953
Energy Group:
Wholesale Energy Operations	46			55			86			106
Retail Gas and Other Operations	20			21			42			43
Subtotal Energy Group	66			76			128			149
Energy Services:
On-Site Energy Production	6,165			3,958			11,940			6,970
Appliance Service Operations	67			72			134			146
Subtotal Energy Services	6,232			4,030			12,074			7,116
Corporate and Services	235			221			454			446
Total Depreciation and Amortization	$	19,290		$	17,256		$	38,089		$	31,664

Interest Charges:
Gas Utility Operations	$	4,292		$	2,789		$	8,634		$	5,750
Energy Group:
Wholesale Energy Operations	(5		)	33			116			85
Retail Gas and Other Operations	68			67			194			143
Subtotal Energy Group	63			100			310			228
Energy Services:
On-Site Energy Production	2,147			307			4,275			1,710
Corporate and Services	1,790			1,212			3,640			2,720
Subtotal	8,292			4,408			16,859			10,408
Intersegment Borrowings	(1,446		)	(988		)	(2,929		)	(2,280		)
Total Interest Charges	$	6,846		$	3,420		$	13,930		$	8,128

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	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
Income Taxes:
Gas Utility Operations	$	2,379		$	2,269		24,906			23,040
Energy Group:
Wholesale Energy Operations	(2,628		)	(7,710		)	(3,181		)	(9,691		)
Retail Gas and Other Operations	80			(52		)	1,016			220
Retail Electric Operations	(343		)	(139		)	(365		)	51
Subtotal Energy Group	(2,891		)	(7,901		)	(2,530		)	(9,420		)
Energy Services:
On-Site Energy Production	(9,404		)	(6,466		)	(20,429		)	(18,030		)
Appliance Service Operations	211			338			188			342
Subtotal Energy Services	(9,193		)	(6,128		)	(20,241		)	(17,688		)
Corporate and Services	195			128			224			208
Total Income Taxes	$	(9,510	)	$	(11,632	)	$	2,359		$	(3,860	)

Property Additions:
Gas Utility Operations	$	59,067		$	44,764		$	91,598		$	81,806
Energy Group:
Wholesale Energy Operations	8			25			10			34
Retail Gas and Other Operations	229			35			397			37
Subtotal Energy Group	237			60			407			71
Energy Services:
On-Site Energy Production	16,426			14,949			25,575			17,526
Appliance Service Operations	6			—			6			—
Subtotal Energy Services	16,432			14,949			25,581			17,526
Corporate and Services	803			1,126			1,581			1,864
Total Property Additions	$	76,539		$	60,899		$	119,167		$	101,267



	June 30, 2014			December 31, 2013
Identifiable Assets:
Gas Utility Operations	$	2,009,849		$	1,909,126
Energy Group:
Wholesale Energy Operations	300,680			331,182
Retail Gas and Other Operations	34,424			50,384
Retail Electric Operations	25,850			25,496
Subtotal Energy Group	360,954			407,062
Energy Services:
On-Site Energy Production	605,781			576,315
Appliance Service Operations	2,768			1,812
Subtotal Energy Services	608,549			578,127
Discontinued Operations	1,772			1,068
Corporate and Services	390,939			406,245
Intersegment Assets	(365,525		)	(376,773		)
Total Identifiable Assets	$	3,006,538		$	2,924,855

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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 November 2013, SJG filed a base rate case with the BPU requesting to increase its base rates to obtain a certain level of return on its capital investments. SJG expects the base rate case to be concluded during 2014.

In January 2014, SJG credited the accounts of its periodic Basic Gas Supply Service (BGSS) customers with refunds totaling $11.2 million based on a projected over collection, at that time, due to lower gas costs.

In May 2014, SJG filed its annual Energy Efficiency Tracker (“EET”) petition requesting a 0.19% increase in rates to recover the costs of, and the allowed return on, prior investments associated with energy efficiency programs. This petition is currently pending.

In May 2014, SJG filed its annual BGSS and Conservation Incentive Program (“CIP”) petition, requesting a $4.9 million increase in annual revenues. The Petition proposes to recover over a two-year period higher than normal gas costs caused by colder than normal weather. The Petition also proposes to return to customers, through a reduction to the current CIP rate, excess margin recoveries caused by colder than normal weather. This petition is currently pending.

Also in May 2014, SJG received BPU approval to continue the CIP, with certain modifications.

There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2013. See Note 10 to the Consolidated Financial Statements in Item 8 of SJI's Annual Report on Form 10-K as of December 31, 2013.


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, 2013 which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013.

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



	June 30, 2014		December 31, 2013
Environmental Remediation Costs:
Expended - Net	$	28,612	$	29,945
Liability for Future Expenditures	116,029		119,492
Deferred Asset Retirement Obligation Costs	31,576		31,142
Deferred Pension and Other Postretirement Benefit Costs	59,284		59,284
Deferred Gas Costs - Net	37,371		—
Conservation Incentive Program Receivable	—		10,526
Societal Benefit Costs Receivable	3,287		10,408
Premium for Early Retirement of Debt	—		955
Deferred Interest Rate Contracts	5,494		3,735
Energy Efficiency Tracker	11,779		10,420
Pipeline Supplier Service Charges	6,273		7,106
Pipeline Integrity Cost	3,187		2,902
AFUDC - Equity Related Deferrals	9,568		7,810
Other Regulatory Assets	2,265		2,356

Total Regulatory Assets	$	314,725	$	296,081

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DEFERRED GAS COSTS - NET - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. The change from a $19.1 million regulatory liability at December 31, 2013 to a $37.4 million regulatory asset at June 30, 2014 was due to the actual cost of the commodity incurred during the first six months of the year exceeding the gas costs recovered from the customers as a result of higher prices.

CONSERVATION INCENTIVE PROGRAM (CIP) RECEIVABLE – The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. Actual usage per customer was greater than the established baseline during the first six months of 2014 resulting in a payable that is recorded in the table below as a regulatory liability. The change from a receivable to a related payable is primarily the result of colder weather experienced in the region during the first half of 2014.

SOCIETAL BENEFIT COSTS RECEIVABLE - This regulatory asset primarily represents the deferred expenses under the New Jersey Clean Energy Program, which is a mechanism designed to recover costs associated with energy efficiency and renewable energy program. The decrease in the asset is due to colder weather experienced in the region during the first half of 2014 resulting in increased recoveries of the deferred expense.

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



	June 30, 2014		December 31, 2013
Excess Plant Removal Costs	$	38,430	$	40,029
Deferred Revenues - Net	—		19,067
Conservation Incentive Program Payable	9,594		—
Other Regulatory Liabilities	1,768		1,853

Total Regulatory Liabilities	$	49,792	$	60,949

DEFERRED REVENUES – NET – Over/under collections of gas costs are monitored through SJG’s BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. See "Deferred Gas Costs - Net" above.

CONSERVATION INCENTIVE PROGRAM PAYABLE – The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. See "Conservation Incentive Program (CIP) Receivable" above.

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9.	PENSION AND OTHER POSTRETIREMENT BENEFITS:

For the three and six months ended June 30, 2014 and 2013, net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):



	Pension Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
Service Cost	$	1,285		$	1,332		$	2,570		$	2,710
Interest Cost	2,695			2,387			5,390			4,719
Expected Return on Plan Assets	(3,265		)	(2,968		)	(6,530		)	(5,957		)
Amortizations:
Prior Service Cost	43			62			86			125
Actuarial Loss	1,426			2,332			2,852			4,503
Net Periodic Benefit Cost	2,184			3,145			4,368			6,100
Capitalized Benefit Costs	(854		)	(1,268		)	(1,708		)	(2,435		)
Total Net Periodic Benefit Expense	$	1,330		$	1,877		$	2,660		$	3,665



	Other Postretirement Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
Service Cost	$	250		$	259		$	500		$	570
Interest Cost	740			665			1,480			1,365
Expected Return on Plan Assets	(687		)	(601		)	(1,374		)	(1,189		)
Amortizations:
Prior Service Cost (Credits)	38			(71		)	76			(142		)
Actuarial Loss	243			410			486			869
Net Periodic Benefit Cost	584			662			1,168			1,473
Capitalized Benefit Costs	(209		)	(248		)	(418		)	(570		)
Total Net Periodic Benefit Expense	$	375		$	414		$	750		$	903

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

SJI contributed $12.7 million to the pension plans in January 2013. No contributions are expected to be made to the pension plans during 2014. Payments related to the unfunded supplemental executive retirement plan (SERP) are expected to approximate $1.3 million in 2014. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred.

See Note 12 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013, for additional information related to SJI’s pension and other postretirement benefits.

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10.	LINES OF CREDIT:

Credit facilities and available liquidity as of June 30, 2014 were as follows (in thousands):



Company	Total Facility		Usage		Available Liquidity		Expiration Date
SJG:
Commercial Paper Program/Revolving Credit Facility	$	200,000	$	10,000	$	190,000	May 2018
Uncommitted Bank Lines	10,000		—		10,000		Various

Total SJG	210,000		10,000		200,000

SJI:

Revolving Credit Facility	400,000		213,900		186,100		February 2018 (A)

Total SJI	400,000		213,900		186,100

Total	$	610,000	$	223,900	$	386,100

(A) Includes letters of credit outstanding in the amount of $17.2 million.

The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.16% and 0.98% at June 30, 2014 and 2013, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2014 and 2013 were $320.2 million and $275.3 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2014 and 2013 were $390.7 million and $369.5 million, respectively.

The SJI and SJG facilities are provided by a syndicate of banks and contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements) to not more than 0.65 to 1, measured at the end of each fiscal quarter. SJI and SJG were in compliance with this covenant as of June 30, 2014.

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

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11.	COMMITMENTS AND CONTINGENCIES:

GUARANTEES — The Company has recorded a liability of $0.7 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of June 30, 2014 for the fair value of the following guarantees:

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

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

In 2013, the Company received 1) $57.9 million of repayments of advances to LVE; and 2) a $7.9 million note receivable from a third party, which is recorded in the condensed consolidated balance sheets as of June 30, 2014. As of December 31, 2013, LVE was dissolved and the Company incurred a $0.8 million charge to write-off the remaining interest in 2013.

SJI has guaranteed certain obligations of WC Landfill Energy, LLC (WCLE) and BC Landfill Energy, LLC (BCLE), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. WCLE and BCLE have entered into agreements through 2018 and 2027, respectively, with the respective county governments to lease and operate facilities that will produce electricity from landfill methane gas. Although unlikely, the maximum amount that SJI could be obligated for, in the event that WCLE and BCLE do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due, is approximately $4.2 million each year. SJI and its partner in these joint ventures have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees. SJI holds variable interests in WCLE and BCLE but is not the primary beneficiary.

In December 2013, SJI entered into agreements to guarantee certain obligations of WCLE, SC Landfill Energy, LLC, SX Landfill Energy, LLC, FC Landfill Energy, LLC, and AC Landfill Energy, LLC (collectively, the "Landfills"), unconsolidated joint ventures in which Marina has a 50% equity interest in each through Energenic. The landfills have entered into long-term debt agreements which run through 2020. Although unlikely, SJI could be liable through the guarantees for 50% of the outstanding debt along with any interest related to the debt in the event the landfills do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due. As of June 30, 2014, 50% of the currently outstanding debt is $9.2 million. As a result, the Company has recorded a liability of $0.5 million for the fair value of the guarantees, which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of June 30, 2014.

During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20 year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries are providing full energy services to the complex. Marina and its joint venture partner have provided a $5.0 million letter of credit to support certain operating performance obligations of Energenic under the operating agreements. Marina and its partner in this joint venture have entered into a reimbursement agreement that secures reimbursement for Marina of a proportionate share of any payments made by Marina to or on behalf of Energenic.

In June 2014 the parent company of the hotel, casino and entertainment complex announced that it was filing petitions in U. S. Bankruptcy Court to address liquidity issues and facilitate a sale of substantially all of its assets. An auction and the related sale hearing are scheduled to occur during August 2014. The owner of the complex has indicated that it expects to continue normal business operations throughout this process.

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As of June 30, 2014, the Company, through its investment in Energenic, had a net asset of approximately $26.5 million included in Investment in Affiliates on the consolidated balance sheets related to this project. In addition, the Company had approximately $13.8 million included in Notes Receivable - Affiliate on the consolidated balance sheets, due from an Energenic subsidiary, which is secured by certain assets of the central energy center. This note is also subject to a reimbursement agreement that secures reimbursement for the Company, from its joint venture partner, of a proportionate share of any amounts that are not repaid.

As a result of the bankruptcy filing, management has evaluated the investment in this project and the related note receivable and is unable to determine the impact these events might have, if any, on the respective carrying values as of June 30, 2014.

In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, in which Marina has a 50% equity interest, entered into a 30 year contract with a public university to build, own and operate a combined heating, cooling and power system for its main campus in New Jersey. The system commenced commercial operations in September 2013. SJI has guaranteed certain obligations of UMM under the operating and lease agreements between UMM and the university, for the terms of the agreements, commencing with the first year of operations. SJI has guaranteed up to $2.2 million for the first year. This amount is adjusted each year based upon the Consumer Price Index. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.

As of June 30, 2014, SJI had issued $6.6 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, 2014. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76. SJG and SJESP employees represented by the IBEW operate under a collective bargaining agreement that runs through February 2017. The remaining unionized employees are represented by the IAM and operate under a collective bargaining agreement that expires in August 2014.

STANDBY LETTERS OF CREDIT — As of June 30, 2014, SJI provided $17.2 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.

PENDING LITIGATION — The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $2.9 million and $3.0 million related to all claims in the aggregate as of June 30, 2014 and December 31, 2013, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.

ENVIRONMENTAL REMEDIATION COSTS — SJI incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. SJI and some of its nonutility subsidiaries also recorded costs for environmental cleanup of sites where SJF previously operated a fuel oil business and Morie maintained equipment, fueling stations and storage. There have been no changes to the status of the Company’s environmental remediation efforts since December 31, 2013 as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013.

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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, 2014, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 28.7 MMdts (1 MMdts = one million decatherms) of expected future purchases of natural gas, 21.7 MMdts of expected future sales of natural gas, 1.1 MMmwh (1 MMmwh = one million megawatt hours) of expected future purchases of electricity and 1.1 MMmwh of expected future sales of electricity. In addition to these derivative contracts, the Company has basis and index related purchase and sales contracts totaling 53.6 MMdts. These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives — Energy Related Assets or Derivatives — Energy Related Liabilities on the condensed consolidated balance sheets. The net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility.

The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, some of which have been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the consolidated balance sheets. Beginning in July 2012, hedge accounting was discontinued for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously included in Accumulated Other Comprehensive Loss (AOCL) on the consolidated balance sheets, will be reclassified into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026.

There have been no significant changes to the Company’s active interest rate swaps since December 31, 2013 which are described in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2013.

The fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of June 30, 2014 and December 31, 2013, are as follows (in thousands):



Derivatives not designated as hedging instruments under GAAP	June 30, 2014				December 31, 2013
	Assets		Liabilities		Assets		Liabilities
Energy related commodity contracts:
Derivatives – Energy Related – Current	$	58,213	$	93,123	$	56,327	$	77,993
Derivatives – Energy Related – Non-Current	13,106		17,247		26,451		22,131
Interest rate contracts:
Derivatives - Other	—		8,740		—		6,676
Total derivatives not designated as hedging instruments under GAAP	71,319		119,110		82,778		106,800

Total Derivatives	$	71,319	$	119,110	$	82,778	$	106,800

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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, 2014 and December 31, 2013, information related to these offsetting arrangements were as follows (in thousands):



As of June 30, 2014
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Financial Instruments				Cash Collateral Posted		Net amount
Derivatives - Energy Related Assets	$	71,319		$	—	$	71,319		$	(27,113	)	(A)	$	—	$	44,206
Derivatives - Energy Related Liabilities	$	(110,370	)	$	—	$	(110,370	)	$	27,113		(B)	$	21,951	$	(61,306	)
Derivatives - Other	$	(8,740	)	$	—	$	(8,740	)	$	—			$	—	$	(8,740	)



As of December 31, 2013
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet							Net amount
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Financial Instruments				Cash Collateral Posted			Net amount
Derivatives - Energy Related Assets	$	82,778		$	—	$	82,778		$	(28,082	)	(A)	$	(498	)	$	54,198
Derivatives - Energy Related Liabilities	$	(100,124	)	$	—	$	(100,124	)	$	28,082		(B)	$	29,639		$	(42,403	)
Derivatives - Other	$	(6,676	)	$	—	$	(6,676	)	$	—			$	—		$	(6,676	)

(A) The balances at June 30, 2014 and December 31, 2013 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at June 30, 2014 and December 31, 2013 were related to derivative assets which can be net settled against derivative liabilities.

The effect of derivative instruments on the condensed consolidated statements of income for the six months ended June 30, 2014 and 2013 are as follows (in thousands):



	Three Months Ended June 30,						Six Months Ended June 30,
Derivatives in Cash Flow Hedging Relationships under GAAP	2014			2013			2014			2013
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$	—		$	—		$	—		$	—
Losses reclassified from AOCL into income (a)	$	(112	)	$	(112	)	$	(224	)	$	(224	)
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	2014			2013			2014			2013
Gains (losses) on energy related commodity contracts (a)	$	(195	)	$	(16,722	)	$	(28,796	)	$	(23,771	)
(Losses) gains on interest rate contracts (b)	(91		)	1,250			(305		)	1,775

Total	$	(286	)	$	(15,472	)	$	(29,101	)	$	(21,996	)

(a) Included in Operating Revenues - Non Utility

(b) Included in Interest Charges

Net realized gains associated with SJG's energy-related financial commodity contracts of $1.2 million and $1.3 million for the three months ended June 30, 2014 and 2013, respectively, and a gain of $3.6 million and a loss of $0.2 million for the six months ended June 30, 2014 and 2013, respectively, are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy related financial commodity contracts are deferred in Regulatory Assets or Liabilities and there is no impact to earnings.

Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on June 30, 2014, is $45.2 million. If the credit-risk-related contingent features underlying these agreements were triggered on June 30, 2014, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $37.8 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, 2014	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	9,114	$	9,114	$	—	$	—
Derivatives – Energy Related Assets (B)	71,319		4,168		18,818		48,333
	$	80,433	$	13,282	$	18,818	$	48,333

Liabilities

Derivatives – Energy Related Liabilities (B)	$	110,370	$	1,776	$	55,492	$	53,102
Derivatives – Other (C)	8,740		—		8,740		—
	$	119,110	$	1,776	$	64,232	$	53,102



As of December 31, 2013	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	8,716	$	8,716	$	—	$	—
Derivatives – Energy Related Assets (B)	82,778		4,385		27,182		51,211
	$	91,494	$	13,101	$	27,182	$	51,211

Liabilities

Derivatives – Energy Related Liabilities (B)	$	100,124	$	4,236	$	52,772	$	43,116
Derivatives – Other (C)	6,676		—		6,676		—
	$	106,800	$	4,236	$	59,448	$	43,116

(A) Available-for-Sale Securities include securities that are traded in active markets. 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.

(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 consist of forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.

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

The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands):



Type	Fair Value at June 30, 2014		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$39,977	$46,696	Discounted Cash Flow	Forward price (per dt)	$(2.59) - $8.78 [$(1.18)]
Forward Contract - Electric	$8,356	$6,406	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [54.62%]
Forward Contract - Electric	$8,356	$6,406	Discounted Cash Flow	Fixed electric load profile (off-peak)	0.00% - 91.94% [45.38%]



Type	Fair Value at December 31, 2013				Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets		Liabilities
Forward Contract - Natural Gas	$	41,444	$	36,043	Discounted Cash Flow	Forward price (per dt)	$(1.75) - $6.05 [$(0.79)]
Forward Contract - Electric	$	9,767	$	7,073	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.06% - 100.00% [54.55%]
Forward Contract - Electric	$	9,767	$	7,073	Discounted Cash Flow	Fixed electric load profile (off-peak)	0.00% - 91.94% [45.45%]

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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, 2014 and 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):



	Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
Balance at beginning of period	$	(4,971	)	$	8,095
Other changes in fair value from continuing and new contracts, net	(2,252		)	(14,376		)
Settlements	2,454			1,512

Balance at end of period	$	(4,769	)	$	(4,769	)



	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
Balance at beginning of period	1,627			2,762
Other changes in fair value from continuing and new contracts, net	(12,022		)	(12,723		)
Transfers in/(out) of Level 3 (A)	928			928
Settlements	952			518

Balance at end of period	$	(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.

Total losses for 2014 included in earnings that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of June 30, 2014, is $2.3 million. These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.


14.	LONG-TERM DEBT:

In January 2014, SJG issued $30.0 million aggregate principal amount of 4.23% Medium Term Notes due January 2030.

In June 2014, SJG entered into a $200.0 million multiple-draw term facility offered by a syndicate of banks which expires in June, 2017. SJG can draw under this facility through June, 2016 and this facility bears interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. As of June 30, 2014, SJG had borrowed an aggregate $59.0 million under this facility and the proceeds were used to pay down short-term debt.

In June 2014, SJI issued $60.0 million aggregate principal amount of 3.05% Senior Notes due June 2019, and $40.0 million aggregate principal amount of Floating Rate Senior Notes due June 2019. At June 30, 2014, the floating rate was 1.56%.

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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, 2014 (in thousands):




	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities		Other Comprehensive Income (Loss) of Affiliated Companies			Total
Balance at April 1, 2014 (a)	$	(18,503	)	$	(2,631	)	$	459	$	25		$	(20,650	)
Other comprehensive income before reclassifications	—			—			154		—			154
Amounts reclassified from AOCL (b)	—			66			—		(82		)	(16		)
Net current period other comprehensive income (loss)	—			66			154		(82		)	138
Balance at June 30, 2014 (a)	$	(18,503	)	$	(2,565	)	$	613	$	(57	)	$	(20,512	)



	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities		Other Comprehensive Income (Loss) of Affiliated Companies			Total
Balance at January 1, 2014 (a)	$	(18,503	)	$	(2,697	)	$	397	$	43		$	(20,760	)
Other comprehensive income before reclassifications	—			—			216		—			216
Amounts reclassified from AOCL (b)	—			132			—		(100		)	32
Net current period other comprehensive income (loss)	—			132			216		(100		)	248
Balance at June 30, 2014 (a)	$	(18,503	)	$	(2,565	)	$	613	$	(57	)	$	(20,512	)

(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, 2014:



	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Consolidated Statements of Income
	Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	112		$	224		Interest Charges
Income Taxes	(46		)	(92		)	Income Taxes (a)
	$	66		$	132

Loss of Affiliated Companies	$	(134	)	$	(162	)	Equity in Loss of Affiliated Companies
Income Taxes	52			62			Income Taxes (a)
	$	(82	)	$	(100	)

(Losses) Gains from reclassifications for the period net of tax	$	(16	)	$	32

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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, 2013 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, 2013.

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, 2013. 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, 2013.

Environmental Remediation —There have been no significant changes to the status of the Company’s environmental remediation efforts since December 31, 2013. 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, 2013.

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RESULTS OF OPERATIONS:

SJI operates in several different reportable operating segments. These segments are as follows:


•	Gas utility operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers.


•	Wholesale energy operations include the activities of 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.

Net Income for the three months ended June 30, 2014 increased $8.7 million to $9.6 million compared with the same period in 2013 primarily as a result of the following:

•

The income contribution from the wholesale energy operations at SJRG for the three months ended June 30, 2014 increased $6.2 million to a net loss of $5.1 million due primarily to a $9.8 million change in unrealized gains and losses on derivatives used by the wholesale energy operations to mitigate natural gas commodity price risk, as discussed under Operating Revenues - Energy Group below, partially offset by a $3.1 million decrease resulting from lower storage volumes sold and higher transportation charges as described in Gross Margin - Energy Group below.


•	The income contribution from on-site energy production at Marina for the three months ended June 30, 2014 increased $2.4 million to $10.2 million due primarily to the timing of the investment tax credit available on renewable energy facilities as compared to the prior year.

Net Income for the six months ended June 30, 2014 increased $13.8 million to $57.5 million compared with the same period in 2013 primarily as a result of the following:

•

The income contribution from the wholesale energy operations at SJRG for the six months ended June 30, 2014 increased $8.2 million to a net loss of $6.2 million due primarily to a $12.3 million increase related to higher storage volumes sold and higher daily trading margins as described in Gross Margin - Energy Group below, partially offset by a $3.3 million decrease resulting from the change in unrealized gains and losses on derivatives used by the wholesale energy operations to mitigate natural gas commodity price risk, as discussed under Operating Revenues - Energy Group below.


•	The income contribution from on-site energy production at Marina for the six months ended June 30, 2014 increased $2.5 million to $20.3 million due primarily to the timing of the investment tax credit available on renewable energy facilities as compared to the prior year.


•	The income contribution from the gas utility operations at SJG for the six months ended June 30, 2014 increased $2.1 million to $41.5 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:

•

The wholesale energy operations at SJRG purchases and holds natural gas in storage to earn a profit margin from its ultimate sale in the future. The wholesale energy operations 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 injected into 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 the 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.

•

The retail electric operations at SJE uses forward contracts to mitigate commodity price risk on fixed price electric contracts with customers. In accordance with 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 and Economic Earnings per share 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, 2014 and 2013:

•

For the three and six months ended June 30, 2013, Economic Earnings excludes a $0.1 million gain and a $0.8 million loss (both 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 ("LVE," 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. LVE was dissolved prior to December 31, 2013; as such, there was no gain/loss from affiliated companies not part of ongoing operations for the three and six months ended June 30, 2014.

•

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.

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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.

Economic Earnings for the three months ended June 30, 2014 increased $0.1 million to $10.0 million compared with the same period in 2013, primarily as a result of the following:


•	The income contribution from on-site energy production at Marina for the three months ended June 30, 2014 increased $3.2 million to $10.3 million due primarily to the timing of the investment tax credit available on renewable energy facilities as compared to the prior year.


•	The income contribution from the wholesale energy operations at SJRG for the three months ended June 30, 2014 decreased $3.1 million to a net loss of $5.3 million due to lower storage volumes sold and higher transportation charges as described in Gross Margin - Energy Group below.

Economic Earnings for the six months ended June 30, 2014 increased $17.8 million to $76.2 million compared with the same period in 2013 primarily as a result of the following:


•	The income contribution from the wholesale energy operations at SJRG for the six months ended June 30, 2014 increased $12.3 million to $11.2 million due primarily to higher storage volumes sold and higher daily trading margins as described in Gross Margin - Energy Group below.


•	The income contribution from on-site energy production at Marina for the six months ended June 30, 2014 increased $2.8 million to $20.5 million due primarily to the timing of the investment tax credit available on renewable energy facilities as compared to the prior year.


•	The income contribution from the gas utility operations at SJG for the six months ended June 30, 2014 increased $2.1 million to $41.5 million due primarily to increases in the accelerated infrastructure programs and customer growth over the prior year.

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,
	2014			2013			2014			2013
Income from Continuing Operations	$	9,701		$	916		$	57,912		$	44,253
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives	222			9,210			17,880			13,308
Realized (Gains)/Losses on Inventory Injection Hedges	98			(115		)	420			5
Net (Gains) Losses from Affiliated Companies, Not Part of Ongoing Operations (A)	—			(101		)	—			805
Other (B)	(25		)	(25		)	(50		)	(50		)
Economic Earnings	$	9,996		$	9,885		$	76,162		$	58,321

Earnings per Share from Continuing Operations	$	0.29		$	0.03		$	1.76		$	1.39
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives	0.01			0.29			0.55			0.42
Realized (Gains)/Losses on Inventory Injection Hedges	—			(0.01		)	—			—
Net Loss from Affiliated Companies, Not Part of Ongoing Operations (A)	—			—			—			0.02
Economic Earnings per Share	$	0.30		$	0.31		$	2.31		$	1.83

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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,
	2014			2013			2014			2013
Losses on energy related commodity contracts	$	(195	)	$	(16,722	)	$	(28,796	)	$	(23,771	)
(Losses) gains on interest rate contracts	(91		)	1,250			(305		)	1,775
Total before income taxes	(286		)	(15,472		)	(29,101		)	(21,996		)
Income taxes (C)	117			6,344			11,888			9,018
Total after income taxes	(169		)	(9,128		)	(17,213		)	(12,978		)
Unrealized mark-to-market losses on derivatives held by affiliated companies, net of tax (C)	(53		)	(82		)	(667		)	(330		)
Total unrealized mark-to-market losses on derivatives	(222		)	(9,210		)	(17,880		)	(13,308		)
Realized losses on inventory injection hedges, net of tax (C)	(98		)	115			(420		)	(5		)
Net Gain (Loss) from Affiliated Companies, Not Part of Ongoing Operations (A)	—			101			—			(805		)
Other (B)	25			25			50			50
Total reconciling items between income from continuing operations and economic earnings	$	(295	)	$	(8,969	)	$	(18,250	)	$	(14,068	)

(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 following tables summarize the composition of selected gas utility operations 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,
	2014	2013	2014	2013
Utility Throughput – dt:
Firm Sales -
Residential	2,830	2,805	16,018	13,875
Commercial	747	671	3,482	3,187
Industrial	33	29	190	183
Cogeneration & Electric Generation	245	420	555	565
Firm Transportation -
Residential	392	447	2,294	2,075
Commercial	1,081	1,078	4,532	4,064
Industrial	3,159	3,161	6,669	6,728
Cogeneration & Electric Generation	1,229	1,692	3,189	3,774

Total Firm Throughput	9,716	10,303	36,929	34,451

Interruptible Sales	—	14	—	14
Interruptible Transportation	338	305	706	739
Off-System	1,088	1,454	3,518	3,167
Capacity Release	14,477	7,146	30,659	20,961

Total Throughput - Utility	25,619	19,222	71,812	59,332



	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2013		2014		2013
Utility Operating Revenues:
Firm Sales -
Residential	$	35,099	$	33,798	$	160,287	$	141,922
Commercial	9,119		7,767		37,450		31,402
Industrial	586		529		2,667		2,157
Cogeneration & Electric Generation	1,581		2,380		3,661		3,163
Firm Transportation -
Residential	2,697		3,075		12,855		12,364
Commercial	4,509		4,031		17,963		15,362
Industrial	6,184		5,374		12,974		11,318
Cogeneration & Electric Generation	1,248		1,371		3,574		3,605

Total Firm Revenues	61,023		58,325		251,431		221,293

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	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
Interruptible Sales	—			339			2			339
Interruptible Transportation	411			375			859			915
Off-System	5,415			6,573			23,966			13,255
Capacity Release	1,952			687			2,848			4,374
Other	358			237			598			458
	69,159			66,536			279,704			240,634
Less: Intercompany Sales	(256		)	(496		)	(472		)	(943		)
Total Utility Operating Revenues	68,903			66,040			279,232			239,691
Less:
Cost of Sales - Utility (Excluding depreciation)	24,623			25,611			127,700			102,766
Conservation Recoveries*	4,951			2,748			15,718			8,072
RAC Recoveries*	2,022			2,177			4,043			4,355
EET Recoveries*	992			1,195			2,051			2,191
Revenue and Throughput Taxes	175			696			611			2,940
Utility Margin**	$	36,140		$	33,613		$	129,109		$	119,367

Margin:
Residential	$	22,477		$	21,624		$	96,071		$	81,136
Commercial and Industrial	11,430			9,645			37,457			30,924
Cogeneration and Electric Generation	1,100			1,208			2,447			2,438
Interruptible	16			56			34			80
Off-System & Capacity Release	467			232			1,120			917
Other Revenues	872			499			1,111			765
Margin Before Weather Normalization & Decoupling	36,362			33,264			138,240			116,260
CIRT Mechanism	—			734			—			1,476
CIP Mechanism	(409		)	(514		)	(9,419		)	1,377
EET Mechanism	187			129			288			254
Utility Margin**	$	36,140		$	33,613		$	129,109		$	119,367

Degree Days:	476			495			3,262			2,952

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

**Utility Margin is further defined under the caption "Margin - Gas Utility Operations" below.

Throughput - Gas Utility Operations - Total gas throughput increased 6.4 MMdts, or 33.3%, during the three months ended June 30, 2014, compared with the same period in 2013, primarily due to higher capacity release. Capacity release increased 7.3 MMdts as a result of the expiration of an Asset Management Agreement (AMA) that was in effect during 2013. Volumes released under AMA's are not included in the throughput table above. In 2014, the capacity previously committed under the expired AMA was available to be released during 2014. While capacity release can create significant volatility in throughput, it has little impact on revenue and margin generated from such activity. Firm throughput decreased 0.6 MMdts, or 5.7%, during the second quarter of 2014 as a result of system problems at one of SJG's cogeneration customer's facilities during the second quarter.

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Total gas throughput increased 12.5 MMdts, or 21.0%, during the six months ended June 30, 2014, compared with the same period in 2013. Firm throughput increased 2.5 MMdts, or 7.2%, during the first six months of 2014 as a result of weather that was 10.5% colder than the same period last year. Also contributing to higher throughput was the addition of 4,005 customers over the last 12 months, representing 1.1% customer growth. Off-System Sales (OSS) and Capacity Release throughput increased 0.4 MMdts and 9.7 MMdts, respectively, during the first six months of 2014. Similar to firm throughput, OSS throughput improved as a result of higher weather-driven demand during the first quarter. The increase in capacity release was related to the expiration of the AMA that was in effect during 2013. As discussed above, the capacity previously committed under the AMA was available to be released during the first six months of 2014.

Conservation Incentive Program (CIP) - Gas Utility Operations - The effects of the CIP on net income of the gas utility operations for the three and six months ended June 30, 2014 and 2013 and the associated weather comparisons are as follows ($’s in millions):



	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
Net Income Impact:
CIP – Weather Related	$	0.4		$	—		$	(5.7	)	$	(0.7	)
CIP – Usage Related	(0.7		)	(0.3		)	0.1			1.5
Total Net Income Impact	$	(0.3	)	$	(0.3	)	$	(5.6	)	$	0.8

Weather Compared to 20-Year Average	0.1% Warmer			Average			13.4% Colder			1.8% Colder
Weather Compared to Prior Year	3.9% Warmer			34.9% Colder			10.5% Colder			28.5% Colder

Operating Revenues - Gas Utility Operations - Revenues increased $2.9 million, or 4.3%, during the three months ended June 30, 2014, compared with the same period in the prior year after eliminating intercompany transactions. As discussed under "Margin (pre-tax)", the roll in of certain capital investments into base rates effective October 1, 2013, increased revenue by approximately $2.3 million during the second quarter of 2014, compared with the same period last year. The addition of 4,005 customers over the last 12 months and customer migration from firm transportation back to firm sales has also increased total firm revenue, as firm sales include the cost of commodity. While shifts between firm transportation and firm sales result in changes in revenues, it has no impact on profitability, as SJG does not profit from the sale of the commodity.

Revenues increased $39.5 million, or 16.5%, during the six months ended June 30, 2014, compared with the same period in the prior year after eliminating intercompany transactions due to higher firm sales and Off-System Sales (OSS). Total firm revenue increased $30.1 million, or 13.6%, in the first six months of 2014 as a result of 10.5% colder weather and 4,005 additional customers compared with the same period in 2013, as previously discussed under "Throughput-Gas Utility Operations." While colder weather increased firm sales revenue significantly, the revenue increase has little impact on SJG profitability under the operation of the Conservation Incentive Program, as discussed below under the captions "Conservation Incentive Program (CIP)" and "Margin (pre-tax)." As further discussed under "Margin-Gas Utility Operations", the roll in of certain capital investments into base rates effective October 1, 2013, increased revenue by approximately $8.7 million during the first half of 2014.

Higher OSS volume and unit prices resulted in a $10.7 million, or 80.8%, increase in OSS revenues during the six months ended June 30, 2014, compared with the same period in 2013. Colder weather led to greater demand during the first quarter of 2014, allowing SJG to increase revenue from such sales. However, the impact of changes in OSS activity does not have a material impact on the earnings of SJG, as SJG is required to return 85% of the profits of such activity to its ratepayers. Earnings from OSS can be seen in the "Margin" table above.

While changes in gas costs and Basic Gas Supply Service (BGSS) recoveries/refunds may fluctuate from period to period, the gas utility operations do 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-Gas Utility Operations.”

Operating Revenues — Energy Group - Combined revenues for Energy Group, net of intercompany transactions, increased $4.2 million, or 9.6%, to $48.1 million, and $60.5 million, or 53.3%, to $174.0 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013.

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Revenues from retail gas operations at SJE, net of intercompany transactions, increased $0.3 million, or 1.1%, to $24.8 million, and $17.9 million, or 30.6%, to $76.3 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. Excluding the change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(0.1) million and $(0.3) million, revenues increased $0.2 million, or 0.8%, to $24.9 million, and $17.6 million, or 29.9%, to $76.6 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. The change in revenues for the three months ended June 30, 2014 compared to the same period in 2013 was not significant. The increase in revenues for the six months ended June 30, 2014 compared with the same period in 2013 was mainly due to a 29.3% increase in the average monthly New York Mercantile Exchange (NYMEX) settle price, along with a 5.7% increase in sales volumes compared with the same period in 2013. Sales volumes totaled 14,166,835 and 13,397,585 dekatherms for the six months ended June 30, 2014 and 2013, 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.

Revenues from retail electric operations at SJE, net of intercompany transactions, decreased $3.9 million, or 12.8%, and increased $5.7 million, or 9.7%, for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(0.4) million and $(0.1) million, revenues decreased $4.3 million, or 13.6%, and increased $5.6 million, or 9.3%, for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013.

A summary of revenues from retail electric operations at SJE is as follows (in millions):



	Three Months Ended June 30,							Six Months Ended June 30,
	2014		2013		Change			2014		2013		Change
SJE Retail Electric Revenue	$	26.3	$	30.2	$	(3.9	)	$	65.5	$	59.8	$	5.7
Add: Unrealized Losses (Subtract: Unrealized Gains)	0.5		0.9		(0.4		)	0.7		0.8		(0.1		)
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains)	$	26.8	$	31.1	$	(4.3	)	$	66.2	$	60.6	$	5.6

The decrease in revenues from retail electric operations at SJE as defined above for the three months ended June 30, 2014 compared with the same period in 2013 was mainly due to an 11.8% decrease in sales volumes. The increase in revenues from retail electric operations at SJE as defined above for the six months ended June 30, 2014 compared with the same period in 2013 was mainly due to a 25.9% increase in the average monthly sales price, which was driven by a higher average Locational Marginal Price (LMP) per megawatt hour, partially offset by a 14.8% decrease in sales volumes. 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. The retail electric operations at SJE serve both fixed and market-priced customers.

Revenues from wholesale energy operations at SJRG, net of intercompany transactions, increased $7.7 million and $36.8 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(16.1) million and $5.4 million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $0.4 million and $0.7 million to align them with the related cost of inventory in the period of withdrawal, revenues from the wholesale energy operations at SJRG decreased $8.0 million and increased $42.9 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013.

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A summary of revenues from wholesale energy operations at SJRG for the three and six months ended June 30 is as follows (in millions):



	Three Months Ended June 30,									Six Months Ended June 30,
	2014			2013			Change			2014		2013			Change
SJRG Revenue	$	(3.1	)	$	(10.8	)	$	7.7		$	32.0	$	(4.8	)	$	36.8
Add: Unrealized Losses (Subtract: Unrealized Gains)	(0.4		)	15.7			(16.1		)	27.8		22.4			5.4
Add: Realized Losses (Subtract: Realized Gains) on Inventory Injection Hedges	0.2			(0.2		)	0.4			0.7		—			0.7
SJRG Revenue, Excluding Unrealized Losses (Gains) and Realized Losses (Gains) on Inventory Injection Hedges	$	(3.3	)	$	4.7		$	(8.0	)	$	60.5	$	17.6		$	42.9

The decrease in revenues from the wholesale energy operations of SJRG as defined above for the three months ended June 30, 2014 compared with the same period in 2013 was due mainly to a 55.0% decrease in storage volumes sold. The increase in revenues from the wholesale energy operations of SJRG as defined above for the six months ended June 30, 2014 compared with the same period in 2013 was due mainly to a 95.1% increase in storage volumes sold as well as higher margins on daily energy trading activities. 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, 2013, revenues and expenses related to the energy trading activities of the wholesale energy operations at SJRG are presented on a net basis in Operating Revenues – Nonutility on the condensed consolidated income statement.

Operating Revenues - Energy Services - Combined revenues for Energy Services, net of intercompany transactions, increased $3.6 million, or 28.5%, to $16.3 million, and $5.2 million, or 20.8%, to $30.3 million for the three and six months ended June 30, 2014 and 2013, respectively, compared with the same periods in 2013.

Revenues from on-site energy production at Marina, net of intercompany transactions, increased $4.1 million, or 43.1%, to $13.6 million, and $6.4 million, or 34.1%, to $25.0 million for the three and six months ended June 30, 2014 and 2013, respectively, compared with the same periods in 2013 primarily due to several new renewable energy projects that began operations over the past twelve months. Also contributing to the six month comparative period increase is higher hot water production and electricity sales at the wholly-owned thermal facility due to colder temperatures during the first quarter of 2014 as compared to the prior year.

Revenues from appliance service operations at SJESP, net of intercompany transactions, decreased $0.5 million, or 15.8%, to $2.6 million, and $1.2 million. or 17.9%, to $5.3 million for the three and six months ended June 30, 2014 compared with the same periods in 2013 primarily due to lower installation jobs compared to the prior year.

Margin – Gas Utility Operations — The gas utility operations 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, 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 margin increased $2.5 million, or 7.5% for the three month period ended June 30, 2014, compared with the same period in 2013, primarily due to the Capital Investment Recovery Tracker (CIRT) investments rolling into base rates effective October 1, 2013. The CIRT investments rolling into base rates contributed approximately $2.3 million in additional margin during the second quarter of 2014. In addition, SJG added 4,005 customers over the 12-month period ended June 30, 2014, contributing approximately $0.4 million in additional margin during the second quarter 2014, compared with the second quarter of 2013.

Total margin increased $9.7 million, or 8.2%, for the six month period ended June 30, 2014, compared with the same period in 2013, primarily due to the CIRT investments rolling into base rates effective October 1, 2013. The CIRT investments rolling into base rates contributed approximately $8.7 million in additional margin during the first half of 2014. In addition, SJG added 4,005 customers over the 12-month period ended June 30, 2014, representing growth of 1.1% over the prior year and a corresponding increase in margin.

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As reflected in the margin table and the CIP table above, the CIP mechanism requires SJG to return $9.4 million, or $5.6 million after taxes, in margin earned during the six month period ended June 30, 2014 primarily due to weather that was colder than normal. The CIP protected $1.4 million, or $0.8 million after taxes, during the same period in 2013 that would have been lost due to lower customer usage. The impact of the CIP on net income for the three month periods ended June 30, 2014 and 2013 was not material. The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer.

Gross Margin — Non-Utility — Gross margin for the nonutility businesses is defined as revenue less all costs that are directly related to the production, sale 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, 2013, revenues and expenses related to the energy trading activities of the wholesale energy operations at SJRG are presented on a net basis in Operating Revenues - Nonutility on the condensed consolidated income statement.

Gross Margin — Energy Group — For the three and six months ended June 30, 2014, combined gross margins for Energy Group, net of intercompany transactions, increased $10.3 million to a loss of $4.7 million and increased $15.8 million to $0.9 million, respectively, compared with the same periods in 2013. These changes were primarily due to the following:

•

Gross margin from SJE’s retail gas and other operations decreased $0.1 million to $1.2 million and increased $1.8 million to $4.6 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. Excluding the change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(0.1) million and $(0.3) million, gross margins decreased $0.2 million and increased $1.5 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. The change in gross margin for the three months ended June 30, 2014 compared with the same period in 2013 was not significant. The six month comparative period increase was due to increases in sales volumes as discussed in "Operating Revenues-Energy Group" above. 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, 2014, respectively, compared with the same periods in 2013.

•

Gross margin from SJE’s retail electric operations decreased $0.4 million to $0.3 million and $0.4 million to $1.6 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(0.4) million and $(0.1) million, gross margins decreased $0.8 million and $0.5 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. The three and six month comparative period decreases were due to decreases in sales volumes as discussed in "Operating Revenues-Energy Group" above. 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, 2014 as compared with the same periods in 2013.

•

Gross margin from the wholesale energy operations of SJRG increased $10.8 million to a loss of $6.2 million and $14.4 million to a loss of $5.3 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(16.1) million and $5.4 million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $0.4 million and $0.7 million to align them with the related cost of inventory in the period of withdrawal as discussed above, gross margin for the wholesale energy operations of SJRG decreased $4.9 million and increased $20.5 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. The decrease in gross margin for the three months ended June 30, 2014 compared with the same period in 2013 was due mainly to lower storage volumes sold and higher transportation charges as discussed in "Operating Revenues-Energy Group" above. The increase in gross margin for the six months ended June 30, 2014 compared with the same period in 2013 was due mainly to an increase in storage volumes sold as well as higher margins on daily energy trading activities as discussed in "Operating Revenues-Energy Group" above.

The wholesale energy operations at 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, 2014, the wholesale energy operations had 9.1 Bcf of storage and 553,496 dts/day of transportation under contract.

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Gross Margin - Energy Services - For the three and six months ended June 30, 2014, combined gross margins for Energy Services, net of intercompany transactions, increased $5.4 million to $14.8 million and $7.9 million to $23.9 million, respectively, compared with the same periods in 2013. These changes were primarily due to the following:

•

Gross margin from on-site energy production at Marina, net of intercompany transactions, increased $5.7 million to $13.4 million and $8.3 million to $21.6 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. These increases were mainly due to several new renewable energy projects that began operations over the past twelve months. Also contributing to the six month comparative period increase is higher hot water production and electricity sales at the wholly owned thermal facility due to colder temperatures during the first quarter of 2014 as compared to the prior year. Gross margin as a percentage of Operating Revenues did not change significantly for the three and six months ended June 30, 2014 compared with the same periods in 2013.


•	Gross margin from appliance service operations at SJESP , along with gross margin as a percentage of Operating Revenues, did not change significantly for the three and six months ended June 30, 2014 as compared with the same periods in 2013.

Operating Expenses — 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, 2014 vs. 2013			Six Months Ended June 30, 2014 vs. 2013
Gas Utility Operations	$	2,632		$	8,893
Nonutility:
Energy Group:
Wholesale Energy Operations	103			161
Retail Gas and Other Operations	(110		)	(123		)
Retail Electric Operations	139			660
Subtotal Energy Group	132			698
Energy Services:
On-Site Energy Production	77			54
Appliance Service Operations	192			129
Subtotal Energy Services	269			183
Total Nonutility	401			881
Intercompany Eliminations and Other	(338		)	(418		)
Total Operations Expense	$	2,695		$	9,356

Operations - Gas utility operations expense increased $2.6 million and $8.9 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013. These increases are primarily 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, the gas utility operations experienced an offsetting increase in revenues during the period.

Nonutility operations expense increased $0.4 million and $0.9 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013, 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, 2014, respectively, compared with the same periods in 2013, were not significant.

Depreciation - Depreciation increased $3.1 million and $6.7 million during the three and six months ended June 30, 2014, respectively. compared with the same periods in 2013 due mainly to the increased investment in property, plant and equipment by the gas utility operations and on-site energy production at Marina.

Energy and Other Taxes - Energy and other taxes decreased $0.4 million and $2.3 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013 due primarily to the elimination of the gas utility operations' primary energy tax, the Transitional Energy Facilities Assessment, effective January 1, 2014 (see Note 1 to the condensed consolidated financial statements).

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Other Income and Expense - Other income and expense increased $1.5 million during the three months ended June 30, 2014 compared with the same period in 2013 primarily due to the settlement of outstanding litigation at SJEX. The change in other income and expense during the six months ended June 30, 2014 as compared with the same period in 2013 was not significant due primarily to a decrease in interest income on notes receivable from affiliates, which was offset by the settlement of outstanding litigation at SJEX.

Interest Charges – Interest charges increased $3.4 million and $5.8 million for the three and six months ended June 30, 2014, respectively, compared with the same periods in 2013 primarily due to unrealized gains recognized during the three and six months ended June 30, 2013 that did not recur during the same periods in 2014 on interest rate contracts related to derivatives not designated as hedging instruments, which are recorded in Interest Charges on the condensed consolidated statements of income (see Note 12 to the condensed consolidated financial statements). Also contributing to the increase were higher amounts of long-term debt outstanding at SJG and lower capitalization of interest costs on construction at the gas utility operations at SJG during 2014. This was a result of the roll-in of capital investments under SJG's CIRT into base rates effective October 1, 2013, and weather-related construction delays during 2014. CIRT investments were approved by the BPU to accrue interest on construction until such time they were rolled into base rates.

Income Taxes – Income tax benefit decreased $2.1 million for the three months ended June 30, 2014 compared with the same period in 2013. Income taxes went from a $3.9 million benefit to a $2.4 million expense for the six months ended June 30, 2014 compared with the same period in 2013. These comparative period changes were both due primarily to higher income before taxes, along with higher effective tax rates due to a decrease in investment tax credits on renewable energy facilities at Marina in 2014 as compared to 2013.

Equity in Earnings of Affiliated Companies – Equity in earnings of affiliated companies decreased $1.5 million for the three months ended June 30, 2014 compared with the same period in 2013 primarily due to higher maintenance costs incurred to improve the performance of the landfill gas fired electric production facilities compared to the prior year. Equity in earnings of affiliated companies increased $0.8 million for the six months ended June 30, 2014 compared to the same period in 2013 primarily due to higher production at our affiliated companies as a result of colder than normal temperatures for the first quarter of 2014, partially offset by higher maintenance costs incurred to improve the performance of the 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 and other regulatory clauses; 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 $89.7 million and $62.5 million in the first six months of 2014 and 2013, 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 2014 produced more net cash than the same period in 2013 due primarily to lower working capital requirements, primarily as a result of higher customer collections on accounts receivable. This was offset by higher gas costs due to the extremely cold weather during the first three months of 2014. At SJG, a portion of these higher gas costs were deferred and will be collected in future periods under SJG's BGSS. In addition, SJI did not make a pension contribution during the first six months of 2014 as compared to a contribution of $12.7 million for the first six months of 2013. This was due to an increase in the discount rate used to calculate future liability and greater than expected asset performance significantly improving the Company's funding status. 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.

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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 2014 and 2013 amounted to $134.9 million and $88.3 million, respectively. We estimate the net cash outflows for construction projects for fiscal years 2014, 2015 and 2016 at SJI to be approximately $358.7 million, $423.4 million and $296.8 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 Accelerated Infrastructure Replacement Program (AIRP), the Company expects to 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 may refinance the short-term debt incurred to support capital expenditures with long-term debt. Also contributing to the high level of capital expenditures are anticipated solar projects at Marina.

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 is difficult to predict. Margin posted by the Company decreased by $3.3 million in the first six months of 2014, compared with an increase of $13.8 million in the same period of 2013.

In March 2013, substantially all of the assets of Marina's joint venture, LVE Energy Partners, LLC (LVE), an entity in which Marina had a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.9 million in 2013. LVE was dissolved prior to December 31, 2013. See Note 11 to the condensed consolidated financial statements.

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, 2014 were as follows (in thousands):



Company	Total Facility		Usage		Available Liquidity		Expiration Date
SJG:
Commercial Paper Program/Revolving Credit Facility	$	200,000	$	10,000	$	190,000	May 2018
Uncommitted Bank Lines	10,000		—		10,000		Various

Total SJG	210,000		10,000		200,000

SJI:

Revolving Credit Facility	400,000		213,900		186,100		February 2018 (A)

Total SJI	400,000		213,900		186,100

Total	$	610,000	$	223,900	$	386,100

(A) Includes letters of credit outstanding in the amount of $17.2 million.

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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, 2014. Borrowings under these credit facilities are at market rates. The weighted average borrowing cost, which changes daily, was 1.16% and 0.98% at June 30, 2014 and 2013, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2014 and 2013 were $320.2 million and $275.3 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2014 and 2013 were $390.7 million and $369.5 million, 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 (MTN's), 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.

In January 2014, SJG issued $30.0 million aggregate principal amount of 4.23% MTN's due January 2030.

In June 2014, SJG entered into a $200.0 million multiple-draw term facility offered by a syndicate of banks which expires in June, 2017. SJG can draw under this facility through June, 2016 and this facility bears interest at a floating rate based on LIBOR plus a spread determined by SJG's credit ratings. As of June 30, SJG had borrowed an aggregate $59.0 million under this facility and the proceeds were used to pay down short-term debt.

In June 2014, SJI agreed to issue $240.0 million aggregate principal amount long term debt via a private placement as follows:


•	$60.0 million aggregate principal amount of 3.05% Senior Notes and $40.0 million aggregate principal amount of Floating Rate Senior Notes, both drawn in June 2014 and due June 2019. At June 30, 2014, the floating rate was 1.56%.


•	$30.0 million aggregate principal amount of 3.05% Senior Notes to be drawn in August 2014 due August 2019.


•	$50.0 million aggregate principal amount of 3.05% Senior Notes and $60.0 aggregate principal amount of Floating Rate Senior Notes, both to be drawn in September 2014 due September 2019.

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; however, the discount was reinstated during the third quarter of 2013. SJI raised $17.1 million and $12.5 million of equity capital through the DRP during the six months ended June 30, 2014 and 2013, respectively.

SJI’s capital structure was as follows:



	As of June 30, 2014		As of December 31, 2013
Equity	44.3	%	43.9	%
Long-Term Debt	45.2	%	37.3	%
Short-Term Debt	10.5	%	18.8	%
Total	100.0	%	100.0	%

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SJI has paid dividends on its common stock for 63 consecutive years and has increased that dividend each year for the last fourteen 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 2014 and 2013 amounted to $134.9 million and $88.3 million, respectively. Management estimates the net cash outflows for construction projects for 2014, 2015 and 2016 at SJI to be approximately $358.7 million, $423.4million and $296.8 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. Also contributing to the high level of capital expenditures are anticipated solar projects at Marina. Costs for remediation projects, net of insurance reimbursements, for the first six months of 2014 and 2013 amounted to net cash outflows of $2.9 million and inflows of $2.3 million, respectively. Total net cash outflows for remediation projects are expected to be $14.3 million, $35.6 million and $29.3 million for 2014, 2015 and 2016, 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, 2013, certain environmental costs are subject to recovery from insurance carriers and ratepayers.

As of June 30, 2014, SJI provided $17.2 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. The Company 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, 2013, except for 1) long term debt, which increased due to the issuance of $100.0 million aggregate principal amount of Senior Term Notes at SJI, $59.0 million borrowings under a multiple-draw term facility at SJG and $30.0 million aggregate principal amount of MTN's at SJG (see note 14 to the condensed consolidated financial statements); 2) construction obligations, which increased $56.4 million in total since December 31, 2013 due to solar projects entered into at Marina; and 3) commodity supply purchase obligations which increased approximately $121.3 million in total since December 31, 2013 due to increases in transportation agreements at SJRG and additional agreements to extend several services and replenish storage at SJG.

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 $0.7 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of June 30, 2014 for the fair value of the following guarantees:

•

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•

In December 2013, SJI entered into agreements to guarantee certain obligations of WCLE, SC Landfill Energy, LLC, SX Landfill Energy, LLC, FC Landfill Energy, LLC, and AC Landfill Energy, LLC (collectively, the "Landfills"), unconsolidated joint ventures in which Marina has a 50% equity interest in each through Energenic. The Landfills have entered into long-term debt agreements which run through 2020. Although unlikely, SJI could be liable through the guarantees for 50% of the outstanding debt along with any interest related to the debt in the event the Landfills do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due. As of June 30, 2014, 50% of the currently outstanding debt is $9.2 million. As a result, the Company has recorded a liability of $0.5 million for the fair value of the guarantees, which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of June 30, 2014.

•


•	As of June 30, 2014, SJI had issued $6.6 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.

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Pending Litigation — The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $2.9 million and $3.0 million related to all claims in the aggregate as of June 30, 2014 and December 31, 2013, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity Market Risks — 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 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.

As part of its gas purchasing strategy, SJG uses financial contracts to hedge against forward price risk. These contracts are recoverable through SJG’s BGSS, subject to BPU approval. SJE transacts commodities on a physical basis and typically does not enter into financial derivative positions directly. SJRG manages risk in the natural gas markets for SJE as well as for its own portfolio by entering into the types of transactions noted above. 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 pre-tax loss of $(0.2) million and $(16.7) million in earnings during the three months ended June 30, 2014 and 2013, respectively, and a net pre-tax loss of $(28.8) million and $(23.8) million during the six months ended June 30, 2014 and 2013, 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, 2014 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	$	4,018	$	150		$	—		$	4,168
Prices provided by other external sources	19,011		(210		)	17			18,818
Prices based on internal models or other valuable methods	35,184		11,474			1,675			48,333

Total	$	58,213	$	11,414		$	1,692		$	71,319

Liabilities
Source of Fair Value	Maturity <1 Year		Maturity 1 -3 Years			Maturity Beyond 3Years			Total
Prices actively quoted	$	1,428	$	344		$	4		$	1,776
Prices provided by other external sources	44,386		11,302			(196		)	55,492
Prices based on internal models or other valuable methods	47,309		5,094			699			53,102

Total	$	93,123	$	16,740		$	507		$	110,370

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•	NYMEX (New York Mercantile Exchange) is the primary national commodities exchange on which natural gas is traded. Volumes of our NYMEX contracts included in the table above under "Prices actively quoted" are 9.6 million dekatherms (dts) with a weighted average settlement price of $4.26 per dt.


•	Basis represents the differential to the NYMEX natural gas futures contract for delivering gas to a specific location. Volumes of our basis contracts included in the table above under "Prices provided by other external sources" and "Prices based on internal models or other valuable methods" are 55.9 million dts with a weighted average settlement price of $0.09 per dt.


•	Fixed Price Gas Daily represents the price of a NYMEX natural gas futures contract adjusted for the difference in price for delivering the gas at another location. Volumes of our Fixed Price Gas Daily contracts included in the table above under "Prices provided by other external sources" are 2.5 million dts with a weighted average settlement price of $5.58 per dt.


•	Volumes of our discounted index related purchase and sales contracts included in the table above under "Prices provided by other external sources" and "Prices based on internal models or other valuable methods" are 109.6 million dts with a weighted average settlement price of $(0.52) per dt.


•	Volumes of electric included in the table above under "Prices based on internal models or other valuable methods" are less than 0.1 million mwh with a weighted average settlement price of $50.92 per mwh.

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



Net Derivatives — Energy Related Liabilities, January 1, 2014	$	(17,346	)
Contracts Settled During Six Months Ended June 30, 2014, Net	13,351
Other Changes in Fair Value from Continuing and New Contracts, Net	(35,056		)

Net Derivatives — Energy Related Liabilities June 30, 2014	$	(39,051	)

Interest Rate Risk — Our exposure to interest-rate risk relates to short-term and long-term variable-rate borrowings. Variable-rate debt outstanding, including short-term and long-term debt, at June 30, 2014 was $382.8 million and averaged $337.5 million during the first six months of 2014. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $2.0 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: 2013 - 16 b.p. decrease; 2012 - 9 b.p. decrease; 2011 - 33 b.p. increase; 2010 – 13 b.p. decrease; and 2009 – 29 b.p. decrease. At June 30, 2014, our average interest rate on variable-rate debt was 1.02%.

We typically 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, 2014, the interest costs on $714.3 million of our long-term debt was either at a fixed rate or hedged via an interest rate derivative.

As of June 30, 2014, 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

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Credit Risk - As of June 30, 2014, approximately $25.6 million, or 35.9%, of the current and noncurrent Derivatives – Energy Related Assets are with two, investment-grade rated counterparties.

As of June 30, 2014, SJRG had $140.3 million of Accounts Receivable under sales contracts. Of that total, 88.2% 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.

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 Securities Exchange Act) as of June 30, 2014. 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 Securities Exchange Act, during the fiscal quarter ended June 30, 2014 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

In May 2013, the Committee of Sponsoring Organizations of the Treadway Commission (COSO) issued an updated version of its Internal Control - Integrated Framework (2013 Framework). Originally issued in 1992 (1992 Framework), the 1992 Framework remains available during the transition period, which extends to December 15, 2014. As of June 30, 2014, the Company continues to utilize the 1992 Framework and anticipates transitioning to the 2013 Framework by the transition date.

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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

There have been no material changes in our risk factors from those disclosed in Part I, Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 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, 2014, filed with the Securities and Exchange Commission on August 6, 2014, 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.

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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 6, 2014	By:	/s/ Edward J. Graham
			Edward J. Graham
			Chairman of the Board & Chief Executive Officer

Dated:	August 6, 2014	By:	/s/ Stephen H. Clark
			Stephen H. Clark
			Chief Financial Officer