SOUTH JERSEY INDUSTRIES INC - Quarter Report: 2016 June (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10-Q

(Mark one)



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

For the quarterly period ended June 30, 2016



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, 2016 there were 79,477,822 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	10
	Note 3. Affiliations and Discontinued Operations	13
	Note 4. Common Stock	15
	Note 5. Financial Instruments	15
	Note 6. Segments of Business	17
	Note 7. Rates and Regulatory Actions	21
	Note 8. Regulatory Assets & Regulatory Liabilities	22
	Note 9. Pension and Other Postretirement Benefits	24
	Note 10. Lines of Credit	25
	Note 11. Commitments and Contingencies	26
	Note 12. Derivative Instruments	26
	Note 13. Fair Value of Financial Assets and Financial Liabilities	29
	Note 14. Long-Term Debt	31
	Note 15. Accumulated Other Comprehensive Loss	32
	Note 16. Subsequent Event	33
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	34
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	51
Item 4.	Controls and Procedures	54

PART II	OTHER INFORMATION

Item 1.	Legal Proceedings	55
Item 1A.	Risk Factors	55
Item 6.	Exhibits	56

Signatures		57

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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,
	2016			2015
Operating Revenues:
Utility	$	68,273		$	75,294
Nonutility	86,129			102,416
Total Operating Revenues	154,402			177,710
Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility	19,508			24,901
- Nonutility	78,832			66,044
Operations	36,250			33,802
Maintenance	4,259			3,928
Depreciation	22,296			17,430
Energy and Other Taxes	1,243			1,265
Total Operating Expenses	162,388			147,370
Operating (Loss) Income	(7,986		)	30,340

Other Income and Expense	4,361			3,040
Interest Charges	(8,229		)	(7,474		)
(Loss) Income Before Income Taxes	(11,854		)	25,906
Income Taxes	7,189			3,279
Equity in Losses of Affiliated Companies	(133		)	(15,844		)
(Loss) Income from Continuing Operations	(4,798		)	13,341
Loss from Discontinued Operations - (Net of tax benefit)	(29		)	(74		)
Net (Loss) Income	$	(4,827	)	$	13,267

Basic Earnings Per Common Share:
Continuing Operations	$	(0.06	)	$	0.19
Discontinued Operations	—			—
Basic Earnings Per Common Share	$	(0.06	)	$	0.19

Average Shares of Common Stock Outstanding - Basic	75,298			68,467

Diluted Earnings Per Common Share:
Continuing Operations	$	(0.06	)	$	0.19
Discontinued Operations	—			—
Diluted Earnings Per Common Share	$	(0.06	)	$	0.19

Average Shares of Common Stock Outstanding - Diluted	75,298			68,653

Dividends Declared Per Common Share	$	0.26		$	0.25

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

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	Six Months Ended June 30,
	2016			2015
Operating Revenues:
Utility	$	251,942		$	341,824
Nonutility	235,495			218,838
Total Operating Revenues	487,437			560,662
Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility	84,714			169,875
- Nonutility	166,601			162,777
Operations	75,047			75,663
Maintenance	8,643			7,926
Depreciation	42,997			34,249
Energy and Other Taxes	3,168			3,461
Total Operating Expenses	381,170			453,951
Operating Income	106,267			106,711

Other Income and Expense	6,564			5,281
Interest Charges	(17,389		)	(16,075		)
Income Before Income Taxes	95,442			95,917
Income Taxes	(32,078		)	(13,334		)
Equity in Earnings (Losses) of Affiliated Companies	25			(15,389		)
Income from Continuing Operations	63,389			67,194
Loss from Discontinued Operations - (Net of tax benefit)	(147		)	(350		)
Net Income	$	63,242		$	66,844

Basic Earnings Per Common Share:
Continuing Operations	$	0.86		$	0.98
Discontinued Operations	—			—
Basic Earnings Per Common Share	$	0.86		$	0.98

Average Shares of Common Stock Outstanding - Basic	73,213			68,432

Diluted Earnings Per Common Share:
Continuing Operations	$	0.86		$	0.98
Discontinued Operations	—			—
Diluted Earnings Per Common Share	$	0.86		$	0.98

Average Shares of Common Stock Outstanding - Diluted	73,506			68,636

Dividends Declared per Common Share	$	0.52		$	0.50

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,
	2016			2015
Net (Loss) Income	$	(4,827	)	$	13,267

Other Comprehensive Income, Net of Tax:*

Unrealized Gain (Loss) on Available-for-Sale Securities	55			(64		)
Unrealized Gain on Derivatives - Other	49			111
Other Comprehensive Income of Affiliated Companies	—			59

Other Comprehensive Income - Net of Tax*	104			106

Comprehensive (Loss) Income	$	(4,723	)	$	13,373




	Six Months Ended June 30,
	2016		2015
Net Income	$	63,242	$	66,844

Other Comprehensive Income, Net of Tax:*

Unrealized Gain on Available-for-Sale Securities	104		24
Unrealized Gain on Derivatives - Other	100		119
Other Comprehensive Loss of Affiliated Companies	—		(36		)

Other Comprehensive Income - Net of Tax*	204		107

Comprehensive Income	$	63,446	$	66,951

* Determined using a combined average statutory tax rate of 40%.

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,
	2016			2015
Net Cash Provided by Operating Activities	$	158,099		$	102,059

Cash Flows from Investing Activities:
Capital Expenditures	(118,843		)	(141,585		)
Purchase of Available-for-Sale Securities	—			(6,059		)
Proceeds from Restricted Investments	1,738			—
Net Proceeds from Sale of Restricted Investments in Margin Account	7,781			12,581
Investment in Long-Term Receivables	(5,702		)	(3,381		)
Proceeds from Long-Term Receivables	5,195			2,040
Notes Receivable	(74		)	(9,887		)
Purchase of Company-Owned Life Insurance	(652		)	(765		)
Investment in Affiliate	(5,820		)	(1,766		)
Advances on Notes Receivable - Affiliate	—			(1,514		)
Net Repayment of Notes Receivable - Affiliate	1,266			4,612

Net Cash Used in Investing Activities	(115,111		)	(145,724		)

Cash Flows from Financing Activities:
Net (Repayments of) Borrowings from Short-Term Credit Facilities	(286,300		)	120,300
Proceeds from Issuance of Long-Term Debt	61,000			—
Principal Repayments of Long-Term Debt	(13,078		)	(64,000		)
Dividends on Common Stock	(18,790		)	(17,192		)
Proceeds from Sale of Common Stock	214,463			3,596

Net Cash (Used in) Provided by Financing Activities	(42,705		)	42,704

Net Increase (Decrease) in Cash and Cash Equivalents	283			(961		)
Cash and Cash Equivalents at Beginning of Period	3,877			4,171

Cash and Cash Equivalents at End of Period	$	4,160		$	3,210

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, 2016			December 31, 2015
Assets
Property, Plant and Equipment:
Utility Plant, at original cost	$	2,310,223		$	2,211,239
Accumulated Depreciation	(459,015		)	(440,473		)
Nonutility Property and Equipment, at cost	792,256			785,646
Accumulated Depreciation	(128,574		)	(108,307		)

Property, Plant and Equipment - Net	2,514,890			2,448,105

Investments:
Available-for-Sale Securities	15,160			14,810
Restricted	38,177			48,758
Investment in Affiliates	22,168			16,983

Total Investments	75,505			80,551

Current Assets:
Cash and Cash Equivalents	4,160			3,877
Accounts Receivable	175,341			178,359
Unbilled Revenues	29,385			40,044
Provision for Uncollectibles	(10,118		)	(10,252		)
Notes Receivable	11,843			11,800
Notes Receivable - Affiliate	1,868			3,134
Natural Gas in Storage, average cost	44,499			54,211
Materials and Supplies, average cost	6,815			5,088
Prepaid Taxes	27,922			21,753
Derivatives - Energy Related Assets	45,112			83,093
Other Prepayments and Current Assets	38,930			40,167

Total Current Assets	375,757			431,274

Regulatory and Other Noncurrent Assets:
Regulatory Assets	380,364			323,434
Derivatives - Energy Related Assets	11,929			16,238
Notes Receivable - Affiliate	13,275			13,275
Contract Receivables	28,976			28,609
Notes Receivable	31,187			35,439
Goodwill	8,139			8,880
Identifiable Intangible Assets	16,209			21,553
Other	66,350			64,575

Total Regulatory and Other Noncurrent Assets	556,429			512,003

Total Assets	$	3,522,581		$	3,471,933

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, 2016			December 31, 2015
Capitalization and Liabilities
Equity:
Common Stock	$	99,347		$	88,707
Premium on Common Stock	705,106			499,460
Treasury Stock (at par)	(259		)	(296		)
Accumulated Other Comprehensive Loss	(24,295		)	(24,499		)
Retained Earnings	497,648			474,167

Total Equity	1,277,547			1,037,539

Long-Term Debt (See Note 1)	831,089			997,427

Total Capitalization	2,108,636			2,034,966

Current Liabilities:
Notes Payable	145,400			431,700
Current Portion of Long-Term Debt	244,605			29,454
Accounts Payable	166,418			186,400
Customer Deposits and Credit Balances	23,022			20,146
Environmental Remediation Costs	72,315			50,559
Taxes Accrued	2,832			2,336
Derivatives - Energy Related Liabilities	66,444			90,708
Derivatives - Other	945			—
Dividends Payable	20,962			—
Interest Accrued	7,176			7,316
Pension Benefits	2,261			2,261
Other Current Liabilities	6,053			11,596

Total Current Liabilities	758,433			832,476

Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net	330,046			295,945
Pension and Other Postretirement Benefits	79,821			76,068
Environmental Remediation Costs	83,495			76,064
Asset Retirement Obligations	59,032			57,943
Derivatives - Energy Related Liabilities	8,371			21,697
Derivatives - Other	13,386			10,943
Regulatory Liabilities	60,010			42,841
Other	21,351			22,990

Total Deferred Credits and Other Noncurrent Liabilities	655,512			604,491

Commitments and Contingencies (Note 11)

Total Capitalization and Liabilities	$	3,522,581		$	3,471,933

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 wholly-owned 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, industrial and residential customers.


▪	South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets along with fuel management services 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. The following entities are wholly-owned subsidiaries of Marina as of December 31, 2015 (see Note 3):

•ACB Energy Partners, LLC (ACB) owns and operates a natural gas fueled combined heating, cooling and power facility located in Atlantic City, New Jersey.

•AC Landfill Energy. LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE) and SX Landfill Energy, LLC (SXLE) own and operate landfill gas-fired electric production facilities in Atlantic, Burlington, Salem and Sussex Counties located in New Jersey.

•MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS) own and operate solar-generation sites located in New Jersey.


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


▪	SJI Midstream, LLC was formed in 2014 to invest in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.

BASIS OF PRESENTATION — The condensed consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management’s opinion, the condensed consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI’s financial position, operating results and cash flows at the dates and for the periods presented. SJI’s businesses are subject to seasonal fluctuations and, accordingly, this interim financial information should not be the basis for estimating the full year’s operating results. As permitted by the rules and regulations of the Securities and Exchange Commission (SEC), the accompanying unaudited condensed consolidated financial statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These financial statements should be read in conjunction with SJI’s 2015 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.

Certain reclassifications have been made to the prior period's condensed consolidated balance sheets, as well as the prior period's long-term debt carrying value and prior period's segment disclosures in Notes 5 and 6, respectively, to conform to the current period presentation. The unamortized debt issuance costs previously included in "Regulatory and Other Noncurrent Assets" on the condensed consolidated balance sheets were reclassified to Long-Term Debt to conform to ASU 2015-03, which is described below under "New Accounting Pronouncements." This reclassification caused the prior period long-term debt carrying value in Note 5 to be adjusted, along with the prior period unamortized debt issuance costs recorded as Identifiable Assets in the Gas Utility Operations, On-Site Energy Production and Corporate and Services segments in Note 6 to be removed.

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REVENUE-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include the New Jersey State Sales Tax and Public Utilities Assessment (PUA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. The PUA is included in both utility revenue and energy and other taxes and totaled $0.2 million for both the three months ended June 30, 2016 and 2015, and $0.5 million and $0.8 million for the six months ended June 30, 2016 and 2015, respectively.

IMPAIRMENT OF LONG-LIVED ASSETS - SJI reviews the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the six months ended June 30, 2016 and 2015, no impairments were identified.

GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. No impairment charges were recorded during the six months ended June 30, 2016 or 2015. As of June 30, 2016 and December 31, 2015, $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, 2016 and December 31, 2015, SJI held 207,573 and 236,571 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.

GOODWILL - Goodwill was acquired as part of the acquisition of Energenic projects discussed in Note 3 and is a part of the on-site energy production segment. Goodwill represents the excess of the consideration paid over the fair value of identifiable net assets acquired. Goodwill is not amortized, but instead is subject to impairment testing on an annual basis, and between annual tests whenever events or changes in circumstances indicate that the fair value of a reporting unit may be below its carrying amount. No such events have occurred during the six months ended June 30, 2016. Goodwill totaled $8.1 million and $8.9 million on the condensed consolidated balance sheets as of June 30, 2016 and December 31, 2015, respectively.

The following table summarizes the changes in Goodwill for the six months ended June 30, 2016 (in thousands):



	2016
Beginning Balance, January 1	$	8,880
Fair Value Adjustments During Measurement Period (See Note 3)	(741		)
Ending Balance, June 30	$	8,139

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NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2016 or 2015 had, or are expected to have, a material impact on the condensed consolidated financial statements.

In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Management has formed an implementation team that is currently inventorying the contracts with customers and evaluating the impact that adoption of this guidance will have on the Company's financial statement results, as well as the transition method the Company will elect to adopt the guidance.

In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption.

In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Adoption of this guidance did not have an impact on the Company's results of operations; however, balance sheet presentations were modified to conform to this guidance.

In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In January 2016, the FASB issued ASU 2016-01, Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities, which enhances the reporting model for financial instruments and includes amendments to address aspects of recognition, measurement, presentation and disclosure. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2017. Early adoption is permitted for only certain portions of the new guidance. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which establishes a new lease accounting model for lessees. The new standard requires substantially all leases be recognized by lessees on their balance sheet as a right-of-use asset and corresponding lease liability, including leases currently accounted for as operating leases. The new standard also will result in enhanced quantitative and qualitative disclosures, including significant judgments made by management, to provide greater insight into the extent of revenue and expense recognized and expected to be recognized from existing leases. The accounting for leases by the lessor remains relatively the same. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2018, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-05, Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships. The amendments in this guidance clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

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In March 2016, the FASB issued ASU 2016-07, Investments- Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting, which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net). This standard amends ASU 2014-09 (discussed above), to improve the implementation guidance on principal versus agent considerations and whether an entity reports revenue on a gross or net basis. This standard will have the same effective date and transition requirements as ASU 2014-09. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In March 2016, the FASB issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting, which simplifies various aspects of accounting for share-based payment arrangements. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In April 2016, the FASB issued ASU 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing. This standard amends ASU 2014-09 (discussed above) to clarify identifying performance obligations and the licensing implementation guidance. This standard will have the same effective date and transition requirements as ASU 2014-09. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients. This standard amends ASU 2014-09 (discussed above) to provide additional guidance on (a) the objective of the collectibility criterion, (b) the presentation of sales tax collected from customers, (c) the measurement date of non-cash consideration received, (d) practical expedients in respect of contract modifications and completed contracts at transition, and (5) disclosure of the effects of the accounting change in the period of adoption. This standard will have the same effective date and transition requirements as ASU 2014-09. 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:

On April 30, 2015, the shareholders of SJI approved the adoption of the Company's 2015 Omnibus Equity Compensation Plan (Plan), replacing the Amended and Restated 1997 Stock-Based Compensation Plan that had terminated on January 26, 2015. Under the Plan, shares may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. No options were granted or outstanding during the six months ended June 30, 2016 and 2015. No stock appreciation rights have been issued under the plans. During the six months ended June 30, 2016 and 2015, SJI granted 193,184 and 159,416 restricted shares, respectively, to Officers and other key employees under the plans. Performance-based restricted shares vest over a three-year period and are subject to SJI achieving certain market and earnings-based performance targets, which can cause the actual amount of shares that ultimately vest to range from 0% to 200% of the original share units granted.

Beginning in 2015, SJI grants time-based shares of restricted stock, one-third of which vest annually over a three-year period and is limited to a 100% payout. Vesting of time-based grants is contingent upon SJI achieving a return on equity (ROE) of at least 7% during the initial year of the grant and meeting the service requirement. Provided that the 7% ROE requirement is met in the initial year, payout is solely contingent upon the service requirement being met in years two and three of the grant. During the six months ended June 30, 2016 and 2015, Officers and other key employees were granted 57,955 and 47,824 shares of time-based restricted stock, which are included in the shares noted above.

Grants containing market-based performance targets use SJI's total shareholder return (TSR) relative to a peer group to measure performance. As TSR-based grants are contingent upon market and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant on a straight-line basis over the requisite three-year period of each award. In addition, SJI identifies specific forfeitures of share-based awards, and compensation expense is adjusted accordingly over the requisite service period. Compensation expense is not adjusted based on the actual achievement of performance goals. The fair value of TSR-based restricted stock awards on the date of grant is estimated using a Monte Carlo simulation model.

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Through 2014, grants containing earnings-based targets were based on SJI's earnings growth rate per share (EGR) relative to a peer group to measure performance. In 2015, earning-based performance targets included pre-defined EGR and return on equity (ROE) goals to measure performance. Beginning in 2016, performance targets include pre-defined compounded earnings annual growth rate (CEGR) for SJI. As EGR-based, ROE-based and CEGR-based grants are contingent upon performance and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant over the requisite three-year period of each award. The fair value is measured as the market price at the date of grant. The initial accruals of compensation expense are based on the estimated number of shares expected to vest, assuming the requisite service is rendered and probable outcome of the performance condition is achieved. That estimate is revised if subsequent information indicates that the actual number of shares is likely to differ from previous estimates. Compensation expense is ultimately adjusted based on the actual achievement of service and performance targets.

During the six months ended June 30, 2016 and 2015, SJI granted 35,197 and 25,398 restricted shares, respectively, to Directors. Shares issued to Directors vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest.

The following table summarizes the nonvested restricted stock awards outstanding at June 30, 2016 and the assumptions used to estimate the fair value of the awards:



	Grants	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Officers & Key Employees -	2014 - TSR	50,712	$	21.31	20.0	%	0.80	%
	2014 - EGR	50,712	$	27.22	N/A		N/A
	2015 - TSR	33,930	$	26.31	16.0	%	1.10	%
	2015 - EGR, ROE, Time	74,075	$	29.47	N/A		N/A
	2016 - TSR	66,397	$	22.53	18.1	%	1.31	%
	2016 - CEGR, Time	123,309	$	23.52	N/A		N/A

Directors -	2016	35,197	$	23.88	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, 2016 and 2015 (in thousands):



	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Officers & Key Employees	$	798		$	511		$	1,615		$	1,310
Directors	227			186			420			372
Total Cost	1,025			697			2,035			1,682

Capitalized	(106		)	(87		)	(212		)	(178		)
Net Expense	$	919		$	610		$	1,823		$	1,504

As of June 30, 2016, there was $6.1 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the plans. That cost is expected to be recognized over a weighted average period of 2.0 years.

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The following table summarizes information regarding restricted stock award activity during the six months ended June 30, 2016, excluding accrued dividend equivalents:



	Officers &Other Key Employees		Directors		Weighted Average Fair Value
Nonvested Shares Outstanding, January 1, 2016	226,191		26,338		$	26.89
Granted	193,184		35,197		$	23.28
Cancelled/Forfeited	(6,993	)	—		$	25.10
Vested	(13,247	)	(26,338	)	$	29.30
Nonvested Shares Outstanding, June 30, 2016	399,135		35,197		$	24.80

Performance targets during the three-year vesting period were not attained for the 2012 or 2013 Officer and other key employee grants that vested at December 31, 2014 and 2015, respectively. As a result, no shares were awarded in 2015 or 2016 associated with those grants. However, the initial performance hurdle for the 2015 time-based grant was met. As a result, 13,247 shares were awarded to Officers and other key employees during the six months ended June 30, 2016 at a market value of $0.3 million. During the six months ended June 30, 2016 and 2015, SJI granted 35,197 and 25,398 shares to its Directors at a market value of $0.8 million and $0.7 million, respectively. The Company has a policy of issuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of the Plan. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash. At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods. These deferred shares are included in Treasury Stock on the condensed consolidated balance sheets.

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3.	AFFILIATIONS AND DISCONTINUED OPERATIONS:

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.

On December 31, 2015, Energenic, Marina and its joint venture partner entered into two Equity Distribution and Purchase Agreements (the "Transaction"), pursuant to which Marina became the sole owner of eight of the Energenic projects ("Marina Projects") and its joint venture partner became the sole owner of seven other Energenic projects ("Partner Projects"). The Transaction has been accounted for as a distribution of member interests by Energenic to its owners and a business combination through the exchange of member interests in various projects between Marina and its joint venture partner. In connection with the exchange, the joint venture partner provided a $19.5 million note payable to Marina. The note and other existing obligations of the joint venture partner to Marina are included in Notes Receivable on the condensed consolidated balance sheets, with approximately $1.8 million being included as a current asset as of June 30, 2016, as it is due within one year. This note is collateralized by security interests in various energy project assets owned by the joint venture partner, as well as personal guarantees from its principals.

As part of the transaction, each party is relieved of any guarantees related to the Projects in which it no longer has an ownership interest.

The projects that are now wholly-owned by Marina are ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS.

Through December 31, 2015, Marina’s investment in Energenic was accounted for under the equity method of accounting. As such, Marina’s share of the equity value of the projects was included within Investment in Affiliates on the condensed consolidated balance sheets and Marina’s share of the loss or earnings from the projects for the six months ended June 30, 2015 was included within Equity in Earnings (Losses) of Affiliated Companies on the condensed consolidated statements of income. As of December 31, 2015, the assets and liabilities of the projects that are now wholly-owned by Marina are consolidated into the condensed consolidated balance sheets. Beginning in 2016, the respective results from operations and cash flows of the projects that are now wholly-owned by Marina are consolidated into the condensed consolidated statements of income and cash flows. The results of the acquired projects are included in the On-Site Energy Production segment.

The following table summarizes the preliminary purchase price allocation and reflects 100% of the fair values of the assets acquired and the liabilities assumed by the Company in connection with the Transaction. The Company is still awaiting final valuation reports supporting the allocation of the purchase price to certain identifiable intangibles. Total consideration for the step acquisition of the remaining interest in the Marina Projects was $46.0 million, which represents the fair value of the Company’s interest in the Partner Projects exchanged ($31.5 million) as well as the existing value of the Marina Projects immediately prior to the exchange ($14.5 million) (in thousands):




Current assets (excluding inventory)	$	7,804
Inventory	3,154
Note Receivable Received	19,504
Fixed Assets	46,460
Intangible Assets:
Identifiable Intangibles	16,950
Goodwill	8,139
Non-Current Assets	1,873
Current Liabilities	(8,196		)
Note Payable - Affiliate	(16,986		)
Long-Term Debt, including current portion	(21,642		)
Capital Lease Payable	(10,458		)
Other Non-Current Liabilities	(572		)
Fair Value of Consolidated Assets and Liabilities of Acquired Projects	$	46,030

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The recorded amounts for assets and liabilities represent the Company's best estimate as of June 30, 2016. The measurement period adjustments recorded during the six months ended June 30, 2016 did not have a significant impact on the Company's condensed consolidated balance sheet. The pro forma impact of this transaction on the operations of the Company is not significant.

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

PennEast Pipeline Company, LLC (PennEast) - Midstream has a 20% investment in PennEast, which is planning to construct an approximately 100-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, with a target completion of 2018.

During the first six months of 2016 and 2015, the Company made net investments in unconsolidated affiliates of $4.6 million and $1.3 million, respectively. As of June 30, 2016 and December 31, 2015, the outstanding balance of Notes Receivable – Affiliate was $15.1 million and $16.4 million, respectively. As of June 30, 2016, approximately $13.6 million of these notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025. The remaining $1.5 million of these notes are unsecured and accrue interest at variable rates.

SJI holds significant variable interests in these entities but is not the primary beneficiary. Consequently, these entities are accounted for under the equity method because SJI does not have both a) the power to direct the activities of the entity that most significantly impact the entity’s economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the entity or the right to receive benefits from the entity that could potentially be significant to the entity. As of June 30, 2016, the Company had a net asset of approximately $22.2 million included in Investment in Affiliates 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, 2016, is limited to its combined equity contributions and the Notes Receivable-Affiliate in the aggregate amount of $37.3 million.

DISCONTINUED OPERATIONS - 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, 2016 and 2015, were (in thousands, except per share amounts):



	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Loss before Income Taxes:
Sand Mining	$	(18	)	$	(17	)	(164		)	(364		)
Fuel Oil	(27		)	(97		)	(62		)	(163		)
Income Tax Benefits	16			40			79			177
Loss from Discontinued Operations — Net	$	(29	)	$	(74	)	$	(147	)	$	(350	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic and Diluted	$	—		$	—		$	—		$	—

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4.	COMMON STOCK:

The following shares were issued and outstanding:



	2016
Beginning Balance, January 1	70,965,622
New Issuances During the Period:
Dividend Reinvestment Plan	416,862
Stock-Based Compensation Plan	45,338
Public Equity Offering	8,050,000
Ending Balance, June 30	79,477,822

The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $205.6 million was recorded in Premium on Common Stock.

In May 2016, the Company issued and sold 8,050,000 shares of its common stock, par value $1.25 per share at a public offering, raising net proceeds of approximately $203.6 million. The net proceeds from this offering were or will be used for capital expenditures, primarily for regulated businesses, including infrastructure investments at its utility business.

EARNINGS PER COMMON SHARE (EPS) - Basic EPS is based on the weighted-average number of common shares outstanding. The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 186,147 for the three months ended June 30, 2015 and 292,782 and 203,455 for the six months ended June 30, 2016 and 2015, respectively. For the three months ended June 30, 2016, incremental shares of 297,061 were not included in the denominator for the diluted EPS calculation because they would have an antidilutive effect on EPS. These additional 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 $10.8 million and $3.6 million of equity capital through the DRP during the six months ended June 30, 2016 and 2015, respectively. SJI does not intend to issue any more new equity capital via the DRP in 2016. Effective May 1, 2016, SJI switched to purchasing shares on the open market to fund share purchases by DRP participants.


5.	FINANCIAL INSTRUMENTS:

RESTRICTED INVESTMENTS — Marina is required to maintain escrow accounts related to ongoing capital projects as well as unused loan proceeds pending approval of construction expenditures. As of June 30, 2016 and December 31, 2015, the escrowed funds, including interest earned, totaled $2.3 million and $3.4 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, 2016 and December 31, 2015, the balances in these accounts totaled $35.9 million and $43.7 million, respectively.

As of December 31, 2015, in accordance with an outstanding loan agreement which ACB had with a third party, ACB was required to maintain control accounts which included a debt service reserve of $1.7 million. In January 2016, the remaining debt on the loan agreement was paid (see Note 14); as such, there was no reserve as of June 30, 2016.

The carrying amounts of the Restricted Investments approximate their fair values at June 30, 2016 and December 31, 2015, which would be included in Level 1 of the fair value hierarchy (see Note 13).

INVESTMENT IN AFFILIATES - During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex.

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In June 2014, the parent company of the hotel, casino and entertainment complex filed petitions in U.S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. As of December 31, 2015, the Energenic subsidiaries were providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries had not been able to secure a permanent or long-term energy services agreement with the new owner.

In 2015 management of the Company and Energenic evaluated the carrying value of the investment in this project and a related note receivable. Based on the inability of the Energenic subsidiaries to secure a permanent or long-term energy services agreement, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge was included in Equity in Loss of Affiliated Companies during the second quarter of 2015 on the condensed consolidated statements of income.

The central energy center and energy distribution system owned by the Energenic subsidiaries was financed in part by the issuance of bonds during 2011. These bonds were collateralized primarily by certain assets of the central energy center and revenue from the energy services agreement with the hotel, casino and entertainment complex. During 2015, due to the cessation of normal business operations of the complex and the inability of the Energenic subsidiaries to meet its obligations under the bonds, the trustee for the bondholders filed suit to foreclose on certain assets of the central energy center. In November 2015 during settlement discussions, the bondholders alleged, among other things, that they were entitled to recover from Energenic itself, any amounts owed under the bonds that were not covered by the collateral, including principal, interest and attorney’s fees. The bondholders’ assertion was based on inconsistent language in the bond documents. In January 2016, Energenic and certain subsidiaries reached a multi-party settlement with the bondholders. This agreement resolves all outstanding litigation and transfers ownership of the bondholders’ collateral to the owners of the entertainment complex. The Company’s share of this settlement was $7.5 million, which was accrued by Energenic as of December 31, 2015 and paid in 2016. The Company entered into agreements with its insurance carrier and external legal advisors to recover, net of legal costs, approximately $7.0 million of costs associated with the bondholder settlement discussed above, $2.1 million of which has been received as of June 30, 2016 and included in Other Income on the condensed consolidated statements of income. The remaining $4.9 million is expected to be received and recognized into income prior to the end of the year.

As of June 30, 2016, the Company, through its investment in Energenic, had a remaining net asset of approximately $1.1 million included in Investment in Affiliates on the condensed consolidated balance sheets related to cogeneration assets for this project. In addition, the Company had approximately $13.6 million included in Notes Receivable - Affiliate on the condensed consolidated balance sheets, due from Energenic, which is secured by those cogeneration assets. This note is subject to a reimbursement agreement that secures reimbursement for the Company, from its joint venture partner, of a proportionate share of any amounts that are not repaid.

Management will continue to monitor the situation surrounding the complex and will evaluate the carrying value of the investment and the note receivable as future events occur.

NOTE RECEIVABLE - In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The note bears interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. In December 2015 and February 2016, the borrower exercised each option, respectively. SJG holds a first lien security interest on land in Atlantic City as collateral against this note. The carrying amount of this receivable approximates its fair value at June 30, 2016 and December 31, 2015, which would be included in Level 2 of the fair value hierarchy (see Note 13). In July 2016, the note was repaid in full (see Note 16).

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 to ten years with no interest. The carrying amounts of such loans were $11.0 million and $12.9 million as of June 30, 2016 and December 31, 2015, respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the condensed consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.1 million and $1.3 million as of June 30, 2016 and December 31, 2015, respectively. The annualized amortization to interest is not material to the Company’s condensed consolidated financial statements. The carrying amounts of these receivables approximate their fair value at June 30, 2016 and December 31, 2015, which would be included in Level 2 of the fair value hierarchy (see Note 13).

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CREDIT RISK - As of June 30, 2016, approximately $6.1 million, or 10.8%, of the current and noncurrent Derivatives – Energy Related Assets are transacted with two counterparties. One counterparty has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assigned to SJI in the event of default by the counterparty. The second counterparty is investment-grade rated.

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, 2016 and December 31, 2015, 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). The estimated fair values of SJI's long-term debt, including current maturities, as of June 30, 2016 and December 31, 2015, were $1,154.2 million and $1,079.0 million, respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of June 30, 2016 and December 31, 2015, were $1,075.7 million and $1,026.9 million, respectively. The carrying amounts as of June 30, 2016 and December 31, 2015 are net of unamortized debt issuance costs of $8.1 million and $9.0 million, respectively (see Note 1).

OTHER FINANCIAL INSTRUMENTS - The carrying amounts of SJI's other financial instruments approximate their fair values at June 30, 2016 and December 31, 2015.


6.	SEGMENTS OF BUSINESS:

SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. These segments are as follows:


•	Gas utility operations (SJG) consist 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, industrial and residential customers.


•	On-site energy production consists of Marina's thermal energy facility and other energy-related projects. Also included in this segment are the activities of ACB, ACLE, BCLE, SCLE, SXLE, MCS, NBS and SBS. These entities became wholly-owned subsidiaries of Marina on December 31, 2015 (see Note 3).


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


•	The activities of Midstream are a part of the Corporate and Services segment.

SJI groups its nonutility operations into two categories: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes on-site energy production and appliance service operations. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices.

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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,
	2016			2015			2016			2015
Operating Revenues:
Gas Utility Operations	$	68,762		$	75,812		$	256,528		$	343,470
Energy Group:
Wholesale Energy Operations	(1,309		)	33,276			63,765			68,621
Retail Gas and Other Operations	22,305			18,065			52,038			56,143
Retail Electric Operations	43,065			36,186			82,556			65,963
Subtotal Energy Group	64,061			87,527			198,359			190,727
Energy Services:
On-Site Energy Production	23,043			15,136			39,364			28,708
Appliance Service Operations	2,050			2,699			3,938			5,056
Subtotal Energy Services	25,093			17,835			43,302			33,764
Corporate and Services	8,417			7,765			17,293			16,851
Subtotal	166,333			188,939			515,482			584,812
Intersegment Sales	(11,931		)	(11,229		)	(28,045		)	(24,150		)
Total Operating Revenues	$	154,402		$	177,710		$	487,437		$	560,662

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	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Operating (Loss) Income:
Gas Utility Operations	$	9,931		$	11,961		$	85,704		$	85,150
Energy Group:
Wholesale Energy Operations	(31,149		)	15,158			7,095			15,488
Retail Gas and Other Operations	6,250			153			5,491			3,240
Retail Electric Operations	2,277			174			2,862			(8		)
Subtotal Energy Group	(22,622		)	15,485			15,448			18,720
Energy Services:
On-Site Energy Production	4,561			2,177			4,472			1,695
Appliance Service Operations	258			247			302			195
Subtotal Energy Services	4,819			2,424			4,774			1,890
Corporate and Services	(114		)	470			341			951
Total Operating (Loss) Income	$	(7,986	)	$	30,340		$	106,267		$	106,711

Depreciation and Amortization:
Gas Utility Operations	$	15,788		$	14,239		$	31,414		$	28,406
Energy Group:
Wholesale Energy Operations	204			15			408			47
Retail Gas and Other Operations	83			20			168			40
Subtotal Energy Group	287			35			576			87
Energy Services:
On-Site Energy Production	10,895			7,457			20,814			14,508
Appliance Service Operations	91			73			175			147
Subtotal Energy Services	10,986			7,530			20,989			14,655
Corporate and Services	260			458			483			700
Total Depreciation and Amortization	$	27,321		$	22,262		$	53,462		$	43,848

Interest Charges:
Gas Utility Operations	$	4,552		$	5,113		$	9,339		$	10,303
Energy Group:
Wholesale Energy Operations	1			(112		)	65			130
Retail Gas and Other Operations	78			47			210			120
Subtotal Energy Group	79			(65		)	275			250
Energy Services:
On-Site Energy Production	3,442			1,661			6,904			3,976
Corporate and Services	2,858			2,939			6,310			5,927
Subtotal	10,931			9,648			22,828			20,456
Intersegment Borrowings	(2,702		)	(2,174		)	(5,439		)	(4,381		)
Total Interest Charges	$	8,229		$	7,474		$	17,389		$	16,075

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	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Income Taxes:
Gas Utility Operations	$	1,415		$	3,292		$	28,819		$	29,464
Energy Group:
Wholesale Energy Operations	(12,258		)	5,986			2,479			6,853
Retail Gas and Other Operations	2,450			92			2,282			1,668
Retail Electric Operations	931			71			1,170			(3		)
Subtotal Energy Group	(8,877		)	6,149			5,931			8,518
Energy Services:
On-Site Energy Production	110			(12,861		)	(2,902		)	(24,908		)
Appliance Service Operations	126			105			152			97
Subtotal Energy Services	236			(12,756		)	(2,750		)	(24,811		)
Corporate and Services	37			36			78			163
Total Income Taxes	$	(7,189	)	$	(3,279	)	$	32,078		$	13,334

Property Additions:
Gas Utility Operations	$	50,133		$	62,175		$	101,503		$	105,501
Energy Group:
Wholesale Energy Operations	1			375			7			379
Retail Gas and Other Operations	354			392			725			1,121
Subtotal Energy Group	355			767			732			1,500
Energy Services:
On-Site Energy Production	2,665			26,040			5,316			30,421
Appliance Service Operations	251			212			352			328
Subtotal Energy Services	2,916			26,252			5,668			30,749
Corporate and Services	564			537			727			1,601
Total Property Additions	$	53,968		$	89,731		$	108,630		$	139,351



	June 30, 2016			December 31, 2015
Identifiable Assets (See Note 1):
Gas Utility Operations	$	2,410,522		$	2,281,576
Energy Group:
Wholesale Energy Operations	179,809			231,660
Retail Gas and Other Operations	40,581			55,111
Retail Electric Operations	44,958			55,528
Subtotal Energy Group	265,348			342,299
Energy Services:
On-Site Energy Production	776,907			790,231
Appliance Service Operations	3,492			4,885
Subtotal Energy Services	780,399			795,116
Discontinued Operations	1,776			1,545
Corporate and Services	633,685			652,325
Intersegment Assets	(569,149		)	(600,928		)
Total Identifiable Assets	$	3,522,581		$	3,471,933

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7.	RATES AND REGULATORY ACTIONS:

SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU).

In January 2016, SJG provided a Basic Gas Supply Service (BGSS) bill credit of approximately $20.0 million to its residential and small commercial customers. This credit is in addition to an overall rate reduction of 10.3% that was approved by the BPU and took effect in October 2015. SJG’s ability to offer the BGSS bill credit is a direct result of lower wholesale natural gas prices and the overall management of its gas supply portfolio. The BGSS clause serves as a method to pass along increases or decreases in gas costs to customers; therefore, SJG’s income is not affected by BGSS rate adjustments or bill credits.

In February 2016, SJG filed a petition with the BPU for approval to continue its Accelerated Infrastructure Replacement Program (AIRP), which will expire at the end of 2016. In its petition, SJG has requested approval to continue its AIRP for an additional seven years, with program investments totaling approximately $500.0 million, to retire and replace bare steel and cast iron mains, bare steel services, and other aging infrastructure. The petition proposes to recover the costs of, and a return on, future AIRP investments through annual base rate adjustments. The petition also includes a request to reflect in base rates approximately $76.0 million of AIRP investments that will have been made since the conclusion of SJG’s last base rate case in October 2014 through the end 2016. This petition is currently pending.

In February 2016, the BPU approved a $7.9 million revenue decrease to SJG’s Energy Efficiency Tracker (EET), which recovers the cost of, and an allowed return on, investments in Energy Efficiency Programs (EEP). SJG’s original EEPs and its first EEP Extension, approved by the BPU in 2009 and 2013, respectively, ended in July 2013 and August 2015, respectively. The revenue requirements associated with these prior investments decrease over time as they are amortized and recovered. SJG is continuing to make energy efficiency investments under its most recent EEP Extension, which was approved by the BPU in August 2015, and is recovering the costs, and the allowed return on, those investments through the EET.

In April 2016, the BPU approved a $2.6 million net decrease, including taxes, in annual revenues collected from SJG customers through the Societal Benefits Clause (SBC) charge and the Transportation Initiation Clause (TIC) charge, comprised of a $5.2 million increase in revenues from the Remediation Adjustment Clause (RAC) component of the SBC, a $7.1 million decrease in revenues from the Clean Energy Program (CLEP) component of the SBC, and a $0.7 million decrease in TIC revenues, effective May 7, 2016. The increase in the RAC is driven by an increase in costs associated with the remediation of former Manufactured Gas Plants. The decrease in the CLEP component of the SBC is primarily driven by the accumulation of prior year over-recoveries. The decrease in the TIC is driven by a decrease in costs. The SBC and TIC allow SJG to recover costs associated with certain State-mandated programs. SJG does not earn any profit from these charges.

Also in April 2016, SJG filed a petition requesting to increase annual revenues from base rates by $4.4 million, including taxes, to reflect the roll-in of investments made through June 2016 under its Storm Hardening and Reliability Program (“SHARP”), with rates to become effective on October 1, 2016. This petition is currently pending.

In June 2016, SJG filed its annual BGSS and Conservation Incentive Program (CIP) rate adjustment petition, requesting a $0.6 million net decrease in annual revenues to be implemented on October 1, 2016, comprised of a $47.1 million decrease in BGSS revenues and a $46.5 million increase in CIP revenues, both including taxes. The level of BGSS revenues requested in annual BGSS filings is based on forecasted gas costs and customer usage information for the upcoming BGSS/CIP year, which runs from October to September. SJG’s request for a decrease of BGSS revenues is caused primarily by decreases in forecasted gas commodity costs for the upcoming BGSS/CIP year of October 2016 to September 2017. The level of CIP revenues requested in annual CIP filings is based on historical customer usage information, comparing prior CIP year customer usage to normal customer usage. SJG’s request for an increase in CIP revenues is caused primarily by lower than normal customer usage caused by weather that was 16.4% warmer than normal during the 2015-2016 winter. This petition is currently pending.

Also in June 2016, SJG filed its annual EET rate adjustment petition, requesting a $0.8 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with energy efficiency programs (EEPs). The EET rate recovers the forecasted revenue requirements for the upcoming EET year of October 2016 to September 2017. The requested revenue decrease is the result of the investments associated with SJG's original EEPs, approved by the BPU in 2009, and its EEP extension, approved by the BPU in 2013, which ended in July 2013 and August 2015, respectively. The revenue requirements associated with these prior investments decreases over time as they are amortized. This petition is currently pending.

There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2015. See Note 10 to the Consolidated Financial Statements in Item 8 of SJI's Annual Report on Form 10-K for the year ended December 31, 2015.

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8.	REGULATORY ASSETS AND REGULATORY LIABILITIES:

There have been no significant changes to the nature of the Company’s regulatory assets and liabilities since December 31, 2015, which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2015.

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



	June 30, 2016		December 31, 2015
Environmental Remediation Costs:
Expended - Net	$	50,650	$	42,032
Liability for Future Expenditures	152,349		123,194
Deferred Asset Retirement Obligation Costs	42,912		42,430
Deferred Pension and Other Postretirement Benefit Costs	79,779		79,779
Deferred Gas Costs - Net	—		2,701
Conservation Incentive Program Receivable	21,766		2,624
Deferred Interest Rate Contracts	10,363		7,631
Energy Efficiency Tracker	—		496
Pipeline Supplier Service Charges	2,943		3,776
Pipeline Integrity Cost	4,447		4,596
AFUDC - Equity Related Deferrals	11,938		11,423
Other Regulatory Assets	3,217		2,752

Total Regulatory Assets	$	380,364	$	323,434

ENVIRONMENTAL REMEDIATION COSTS - SJG has two regulatory assets associated with environmental costs related to the cleanup of 12 sites where SJG or its predecessors previously operated gas manufacturing plants. The first asset, "Environmental Remediation Cost: Expended - Net," represents what was actually spent to clean up the sites, less recoveries through the Remediation Adjustment Clause (RAC) and insurance carriers. These costs meet the deferral requirements of GAAP, as the BPU allows SJG to recover such expenditures through the RAC. The other asset, "Environmental Remediation Cost: Liability for Future Expenditures," relates to estimated future expenditures required to complete the remediation of these sites. SJG recorded this estimated amount as a regulatory asset with the corresponding current and noncurrent liabilities on the balance sheets under the captions "Current Liabilities" and "Deferred Credits and Other Noncurrent Liabilities." The BPU allows SJG to recover the deferred costs over seven-year periods after they are spent. The increase from December 31, 2015 is a result of expenditures made during the first six months of 2016 and an increase in the expected future expenditures for remediation activities, primarily due to an increase in the scope of the remediation at a site related to additional contamination being discovered.

DEFERRED GAS COSTS - NET - See discussion under "Deferred Revenues - Net" below.

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 less than the established baseline during the 2015 - 2016 winter season and, more notably, during the first six months of 2016, resulting in an increase in the receivable. This is primarily the result of warm weather experienced in the region.

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



	June 30, 2016		December 31, 2015
Excess Plant Removal Costs	$	31,078	$	32,644
Deferred Revenues - Net	18,631		—
Societal Benefit Costs	8,233		10,197
Energy Efficiency Tracker	2,068		—

Total Regulatory Liabilities	$	60,010	$	42,841

DEFERRED REVENUES - NET - Over/under collections of gas costs are monitored through SJG's BGSS mechanism. Net under collected gas costs are classified as a regulatory asset and net over collected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. The BGSS changed from a $2.7 million regulatory asset at December 31, 2015 to a $18.6 million regulatory liability at June 30, 2016 primarily due to the gas costs recovered from customers exceeding the actual cost of the commodity.

ENERGY EFFICIENCY TRACKER (EET) - This regulatory liability primarily represents energy efficiency measures installed in customer homes and businesses. The change from a $0.5 million regulatory asset at December 31, 2015 to a $2.1 million regulatory liability at June 30, 2016 is due to recoveries being greater than the cost of, and allowed return on, investments in the Energy Efficiency Programs. In February 2016, the BPU approved a $7.9 million revenue decrease to SJG’s EET (see Note 7).

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9.	PENSION AND OTHER POSTRETIREMENT BENEFITS:

For the three and six months ended June 30, 2016 and 2015, 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,
	2016			2015			2016			2015
Service Cost	$	1,106		$	1,225		$	2,421		$	2,668
Interest Cost	3,062			2,814			6,062			5,584
Expected Return on Plan Assets	(3,374		)	(3,695		)	(6,754		)	(7,394		)
Amortizations:
Prior Service Cost	53			53			106			106
Actuarial Loss	2,388			2,648			4,697			5,304
Net Periodic Benefit Cost	3,235			3,045			6,532			6,268
Capitalized Benefit Cost	(1,213		)	(1,194		)	(2,400		)	(2,433		)
Deferred Benefit Cost	(161		)	(325		)	(322		)	(325		)
Total Net Periodic Benefit Expense	$	1,861		$	1,526		$	3,810		$	3,510



	Other Postretirement Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Service Cost	$	195		$	231		$	425		$	558
Interest Cost	654			715			1,307			1,487
Expected Return on Plan Assets	(776		)	(749		)	(1,552		)	(1,497		)
Amortizations:
Prior Service Cost	(86		)	152			(172		)	304
Actuarial Loss	261			287			555			671
Net Periodic Benefit Cost	248			636			563			1,523
Capitalized Benefit Cost	(45		)	(271		)	(146		)	(528		)
Deferred Benefit Cost	—			(79		)	—			(79		)
Total Net Periodic Benefit Expense	$	203		$	286		$	417		$	916

Capitalized benefit costs reflected in the table above relate to SJG’s construction program. Deferred benefit costs relate to SJG's deferral of incremental expense associated with the adoption of new mortality tables effective December 31, 2014 and 2015. Deferred benefit costs are expected to be recovered through rates as part of SJG's next base rate case.

SJI contributed $15.0 million to the pension plans in January 2015. No contributions were made to the pension plans during the six months ended June 30, 2016. SJI does not expect to make any contributions to the pension plans in 2016; however, changes in future investment performance and discount rates may ultimately result in a contribution. Payments related to the unfunded supplemental executive retirement plan (SERP) are expected to approximate $2.3 million in 2016. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred.

See Note 12 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2015, 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, 2016 were as follows (in thousands):



Company	Total Facility		Usage			Available Liquidity		Expiration Date
SJG:
Commercial Paper Program/Revolving Credit Facility	$	200,000	$	14,100	(A)	$	185,900	May 2018
Uncommitted Bank Line	10,000		—			10,000		August 2016	(C)

Total SJG	210,000		14,100			195,900

SJI:

Revolving Credit Facility	400,000		134,900		(B)	265,100		February 2018

Total SJI	400,000		134,900			265,100

Total	$	610,000	$	149,000		$	461,000

(A) Includes letters of credit outstanding in the amount of $0.8 million.

(B) Includes letters of credit outstanding in the amount of $2.8 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 1.43% and 0.96% at June 30, 2016 and 2015, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2016 and 2015 were $325.5 million and $274.3 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2016 and 2015 were $467.7 million and $368.1 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, 2016.

SJG has 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 — As part of the Transaction involving the Energenic projects (see Note 3), the Company is relieved of any guarantees from prior periods related to the projects in which it no longer has an ownership interest.

As of June 30, 2016, SJI had issued $5.9 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.

COLLECTIVE BARGAINING AGREEMENTS — Unionized personnel represent approximately 45% of our workforce at June 30, 2016. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76. SJG and SJESP employees represented by the IBEW operate under collective bargaining agreements that run through February 2017. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017.

STANDBY LETTERS OF CREDIT — As of June 30, 2016, SJI provided $2.8 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. SJG provided a $0.8 million letter of credit under its revolving credit facility to support the remediation of environmental conditions at certain locations in SJG's service territory. The Company has also provided $87.5 million of additional letters of credit under separate facilities outside of the revolving credit facilities to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.

PENDING LITIGATION — The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain gas supply and capacity management contract disputes and certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.1 million and $3.2 million related to all claims in the aggregate as of June 30, 2016 and December 31, 2015, 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. Other than the changes discussed in Note 8 to the condensed consolidated financial statements, there have been no changes to the status of the Company’s environmental remediation efforts since December 31, 2015, as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2015.


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, 2016, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 64.2 MMdts (1 MMdts = one million decatherms) of expected future purchases of natural gas, 71.5 MMdts of expected future sales of natural gas, 2.6 MMmwh (1 MMmwh = one million megawatt hours) of expected future purchases of electricity and 2.4 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 148.7 MMdts. These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Energy Related Assets or Derivatives - Energy Related Liabilities on the condensed consolidated balance sheets. The net unrealized pre-tax gains and losses for these energy-related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility.

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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 had been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the condensed consolidated balance sheets. Hedge accounting has been 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 condensed consolidated balance sheets, are being recorded in earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026.

As of June 30, 2016, SJI’s active interest rate swaps were as follows:

Notional Amount

Fixed Interest Rate

Start Date

Maturity

Type

Obligor

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

12,500,000

3.530%

12/1/2006

2/1/2036

Tax-exempt

SJG

12,500,000

3.430%

12/1/2006

2/1/2036

Tax-exempt

SJG

The fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of June 30, 2016 and December 31, 2015, are as follows (in thousands):



Derivatives not designated as hedging instruments under GAAP	June 30, 2016				December 31, 2015
	Assets		Liabilities		Assets		Liabilities
Energy-related commodity contracts:
Derivatives – Energy Related – Current	$	45,112	$	66,444	$	83,093	$	90,708
Derivatives – Energy Related – Non-Current	11,929		8,371		16,238		21,697
Interest rate contracts:
Derivatives - Other - Current	—		945		—		—
Derivatives - Other - Noncurrent	—		13,386		—		10,943
Total derivatives not designated as hedging instruments under GAAP	$	57,041	$	89,146	$	99,331	$	123,348

Total Derivatives	$	57,041	$	89,146	$	99,331	$	123,348

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, 2016 and December 31, 2015, information related to these offsetting arrangements were as follows (in thousands):



As of June 30, 2016
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	$	57,041		$	—	$	57,041		$	(26,263	)	(A)	$	—	$	30,778
Derivatives - Energy Related Liabilities	$	(74,815	)	$	—	$	(74,815	)	$	26,263		(B)	$	12,854	$	(35,698	)
Derivatives - Other	$	(14,331	)	$	—	$	(14,331	)	$	—			$	—	$	(14,331	)

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As of December 31, 2015
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
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	$	99,331		$	—	$	99,331		$	(35,491	)	(A)	$	—	$	63,840
Derivatives - Energy Related Liabilities	$	(112,405	)	$	—	$	(112,405	)	$	35,491		(B)	$	23,045	$	(53,869	)
Derivatives - Other	$	(10,943	)	$	—	$	(10,943	)	$	—			$	—	$	(10,943	)

(A) The balances at June 30, 2016 and December 31, 2015 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at June 30, 2016 and December 31, 2015 were related to derivative assets which can be net settled against derivative liabilities.

The effect of derivative instruments on the condensed consolidated statements of income for the three and six months ended June 30, 2016 and 2015 are as follows (in thousands):



	Three Months Ended June 30,						Six Months Ended June 30,
Derivatives in Cash Flow Hedging Relationships under GAAP	2016			2015			2016			2015
Interest Rate Contracts:
Losses recognized in AOCL on effective portion	$	—		$	—		$	—		$	—
Losses reclassified from AOCL into income (a)	$	(82	)	$	(187	)	$	(168	)	$	(210	)
Gains (losses) recognized in income on ineffective portion (a)	$	—		$	—		$	—		$	—

(a) Included in Interest Charges



	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments under GAAP	2016			2015		2016			2015
(Losses) gains on energy-related commodity contracts (a)	$	(21,371	)	$	14,685	$	(2,716	)	$	7,978
(Losses) gains on interest rate contracts (b)	(229		)	541		(656		)	243

Total	$	(21,600	)	$	15,226	$	(3,372	)	$	8,221

(a) Included in Operating Revenues - Nonutility

(b) Included in Interest Charges

Net realized loss of $1.6 million and $2.1 million for the three months ended June 30, 2016 and 2015, respectively, and a net realized loss of $4.4 million and $4.8 million for the six months ended June 30, 2016 and 2015, respectively, associated with SJG's energy-related financial commodity contracts are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy-related financial commodity contracts are deferred in Regulatory Assets or Liabilities, as applicable, and there is no impact to earnings.

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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, 2016, is $22.1 million. If the credit-risk-related contingent features underlying these agreements were triggered on June 30, 2016, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $20.1 million after offsetting asset positions with the same counterparties under master netting arrangements.


13.	FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES:

GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. The levels of the hierarchy are described below:


•	Level 1: Observable inputs, such as quoted prices in active markets for identical assets or liabilities.


•	Level 2: Inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly; these include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.


•	Level 3: Unobservable inputs that reflect the reporting entity’s own assumptions.

Assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of financial assets and financial liabilities and their placement within the fair value hierarchy.

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, 2016	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	15,160	$	2,985	$	12,175	$	—
Derivatives – Energy Related Assets (B)	57,041		18,379		7,145		31,517
	$	72,201	$	21,364	$	19,320	$	31,517

Liabilities

Derivatives – Energy Related Liabilities (B)	$	74,815	$	16,589	$	24,613	$	33,613
Derivatives – Other (C)	14,331		—		14,331		—
	$	89,146	$	16,589	$	38,944	$	33,613



As of December 31, 2015	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	14,810	$	2,925	$	11,885	$	—
Derivatives – Energy Related Assets (B)	99,331		16,006		24,730		58,595
	$	114,141	$	18,931	$	36,615	$	58,595

Liabilities

Derivatives – Energy Related Liabilities (B)	$	112,405	$	42,170	$	11,008	$	59,227
Derivatives – Other (C)	10,943		—		10,943		—
	$	123,348	$	42,170	$	21,951	$	59,227

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

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

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

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

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

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



Type	Fair Value at June 30, 2016		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$15,413	$20,012	Discounted Cash Flow	Forward price (per dt)	$ 1.56 - $10.34 [$2.37]	(A)
Forward Contract - Electric	$16,104	$13,601	Discounted Cash Flow	Fixed electric load profile (on-peak)	21.43% - 100.00% [56.08%]	(B)
Forward Contract - Electric	$16,104	$13,601	Discounted Cash Flow	Fixed electric load profile (off-peak)	0.00% - 78.57% [43.92%]	(B)

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Type	Fair Value at December 31, 2015		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$29,459	$31,733	Discounted Cash Flow	Forward price (per dt)	$(0.77) - $10.00 [$(2.15)]	(A)
Forward Contract - Electric	$29,136	$27,494	Discounted Cash Flow	Fixed electric load profile (on-peak)	8.47% - 100.00% [56.20%]	(B)
Forward Contract - Electric	$29,136	$27,494	Discounted Cash Flow	Fixed electric load profile (off-peak)	0.00% - 91.53% [43.80%]	(B)

(A) Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas.

(B) Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak.

The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and six months ended June 30, 2016 and 2015, using significant unobservable inputs (Level 3), are as follows (in thousands):



	Three Months Ended June 30, 2016			Six Months Ended June 30, 2016
Balance at beginning of period	$	13,241		$	(632	)
Other changes in fair value from continuing and new contracts, net	(12,073		)	(2,058		)
Settlements	(3,264		)	594

Balance at end of period	$	(2,096	)	$	(2,096	)



	Three Months Ended June 30, 2015			Six Months Ended June 30, 2015
Balance at beginning of period	$	(17,311	)	$	(5,608	)
Other changes in fair value from continuing and new contracts, net	14,376			(2,062		)
Transfers in/(out) of Level 3 (A)	2,054			2,054
Settlements	(1,663		)	3,072

Balance at end of period	$	(2,544	)	$	(2,544	)

(A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the three and six months ended June 30, 2015, $2.1 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data.

Total losses included in earnings for the three and six months ended June 30, 2016 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, 2016, are $12.1 million and $2.1 million, respectively. These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.


14.	LONG-TERM DEBT:

In January 2016, the Company paid $12.7 million to retire outstanding debt for ACB.

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In January 2016, SJG issued $61.0 million of long-term debt at an average interest rate of 1.37% under a $200.0 million aggregate syndicated bank term facility. The facility is now fully drawn. The total outstanding amount under this facility as of June 30, 2016 is $200.0 million, which was reclassified to current portion of long-term debt on the condensed consolidated balance sheets as it is due within one year. SJG is evaluating alternatives, including refinancing or renewing the facility.

As of June 30, 2016, $16.0 million of aggregate principal amount of 2.71% Senior Notes, due June 2017 were reclassified to current portion of long-term debt on the condensed consolidated balance sheets. At this time, the Company plans to pay off this debt at maturity.

The Company did not issue or retire any other long-term debt during the six months ended June 30, 2016.


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, 2016 (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, 2016 (a)	$	(22,145	)	$	(2,078	)	$	(79	)	$	(97	)	$	(24,399	)
Other comprehensive income before reclassifications	—			—			73			—			73
Amounts reclassified from AOCL (b)	—			49			(18		)	—			31
Net current period other comprehensive income (loss)	—			49			55			—			104
Balance at June 30, 2016 (a)	$	(22,145	)	$	(2,029	)	$	(24	)	$	(97	)	$	(24,295	)




	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, 2016 (a)	$	(22,145	)	$	(2,129	)	$	(128	)	$	(97	)	$	(24,499	)
Other comprehensive income before reclassifications	—			—			136			—			136
Amounts reclassified from AOCL (b)	—			100			(32		)	—			68
Net current period other comprehensive income (loss)	—			100			104			—			204
Balance at June 30, 2016 (a)	$	(22,145	)	$	(2,029	)	$	(24	)	$	(97	)	$	(24,295	)

(a) Determined using a combined average statutory tax rate of 40%.

(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, 2016:



	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Consolidated Statements of Income
	Three Months Ended June 30, 2016			Six Months Ended June 30, 2016
Unrealized Loss on Derivatives-Other - interest rate contracts designated as cash flow hedges	$	82		$	168		Interest Charges
Income Taxes	(33		)	(68		)	Income Taxes (a)
	$	49		$	100

Unrealized Gain on Available-for-Sale Securities	$	(33	)	$	(57	)	Other Income
Income Taxes	15			25			Income Taxes (a)
	$	(18	)	$	(32	)

Losses from reclassifications for the period net of tax	$	31		$	68

(a) Determined using a combined average statutory tax rate of 40%.


16.	SUBSEQUENT EVENT:

In July 2016, the $10.0 million note receivable as of June 30, 2016 from a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey (see Note 5), was repaid in full, including interest.

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

Forward-Looking Statements and Risk Factors — This Quarterly Report, including information incorporated by reference, contains forward-looking statements within the meaning of the U.S. Private Securities Litigation Reform Act of 1995.

All statements other than statements of historical fact, including statements regarding future results of operations or financial position, expected sources of incremental margin, strategy, financing needs, future capital expenditures and the outcome or effect of ongoing litigation, are forward-looking. This Quarterly Report uses words such as "anticipate," "believe," "expect," "estimate," "forecast," "goal," "intend," "objective," "plan," "project," "seek," "strategy," "target," "will" and similar expressions to identify forward-looking statements. These forward-looking statements are based on the beliefs and assumptions of management at the time that these statements were made and are inherently uncertain. Forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed in the forward-looking statements. These risks and uncertainties include, but are not limited to, general economic conditions on an international, national, state and local level; weather conditions in SJI’s marketing areas; changes in commodity costs; changes in the availability of natural gas; “non-routine” or “extraordinary” disruptions in SJI’s 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.

These risks and uncertainties, as well as other risks and uncertainties that could cause actual results to differ materially from those expressed in the forward-looking statements, are described in greater detail under the heading “Item 1A. Risk factors” in this Quarterly Report and in SJI’s Annual Report on Form 10-K for the year ended December 31, 2015 and in any other SEC filings incorporated by reference into this Quarterly Report. No assurance can be given that any goal or plan set forth in any forward-looking statement can or will be achieved, and readers are cautioned not to place undue reliance on such statements, which speak only as of the date they are made. SJI undertakes no obligation to revise or update any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law.

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 SJI's Annual Report on Form 10-K for the year ended December 31, 2015.

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, 2015. 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 for the year ended December 31, 2015.

Environmental Remediation —Other than the changes discussed in Note 8 to the condensed consolidated financial statements, there have been no significant changes to the status of the Company’s environmental remediation efforts since December 31, 2015. See detailed discussion concerning Environmental Remediation Costs in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2015.

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RESULTS OF OPERATIONS:

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


•	Gas utility operations (SJG) consist 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, industrial and residential customers.

•

On-site energy production consists of Marina Energy, LLC (Marina's) thermal energy facility and other energy-related projects. Also included in this segment are the activities of ACB Energy Partners, LLC (ACB), AC Landfill Energy, LLC (ACLE), BC Landfill Energy, LLC (BCLE), SC Landfill Energy, LLC (SCLE), SX Landfill Energy, LLC (SXLE), MCS Energy Partners, LLC (MCS), NBS Energy Partners, LLC (NBS) and SBS Energy Partners, LLC (SBS). These entities became wholly-owned subsidiaries of Marina on December 31, 2015 (see Note 3 to the condensed consolidated financial statements).


•	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.


•	SJI Midstream, LLC (Midstream) was formed in 2014 to invest in infrastructure and other midstream projects, including a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey. The activities of Midstream are a part of the Corporate and Services segment.

SJI's net income for the three months ended June 30, 2016 decreased $18.1 million to a net loss of $4.8 million compared with the same period in 2015, primarily as a result of the following:

•

The net income contribution from the wholesale energy operations at SJRG for the three months ended June 30, 2016 decreased $28.2 million to a net loss of $18.8 million. This was primarily due to an approximately $27.0 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, along with an approximately $1.2 million decrease related to lower margins on daily energy trading activities, as discussed under "Gross Margin - Energy Group" below.


•	The net income contribution from on-site energy production at Marina for the three months ended June 30, 2016 increased $5.4 million to $3.6 million. This was primarily due to the following:


◦	$7.7 million increase due to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, which occurred in the second quarter of 2015 (see Note 5 to the condensed consolidated financial statements),


◦	$2.4 million increase due to several new renewable energy projects that began operations over the past twelve months, along with higher prices on solar renewable energy credits (SRECs) compared to the previous year as discussed in "Gross Margin - Energy Services" below.


◦	$1.3 million increase due to a settlement at Marina in 2016 (see in Note 5 to the condensed consolidated financial statements).


◦	$6.0 million decrease due to a projected decrease in the investment tax credits available on renewable energy facilities as compared to the same period in 2015. This reduction is consistent with the previously announced strategy of substantially reducing investment tax credits from solar development in 2016.


•	The net income contribution from retail gas and electric operations at SJE for the three months ended June 30, 2016 increased $4.9 million to $5.1 million, primarily due to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on retail gas as discussed under "Operating Revenues – Energy Group" below.

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SJI's net income for the six months ended June 30, 2016 decreased $3.6 million to $63.2 million compared with the same period in 2015, primarily as a result of the following:

•

The net income contribution from the wholesale energy operations at SJRG for the six months ended June 30, 2016 decreased $4.8 million to $4.7 million. This was primarily due to an approximately $10.4 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, partially offset by an approximately $5.6 million increase related to additional capacity, as discussed under "Gross Margin - Energy Group" below.


•	The net income contribution from on-site energy production at Marina for the six months ended June 30, 2016 decreased $2.2 million to $3.7 million, primarily due to the following:


◦	$14.6 million decrease due to a projected decrease in the investment tax credits available on renewable energy facilities as compared to the same period in 2015. This reduction is consistent with the previously announced strategy of substantially reducing investment tax credits from solar development in 2016.


◦	$8.7 million increase due to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, which occurred in 2015 (see Note 5 to the condensed consolidated financial statements),


◦	$2.4 million increase due to several new renewable energy projects that began operations over the past twelve months, along with higher prices on SRECs compared to the previous year as discussed in "Gross Margin - Energy Services" below.


◦	$1.3 million increase due to a settlement at Marina in 2016 (see in Note 5 to the condensed consolidated financial statements).


•	The net income contribution from retail gas and electric operations at SJE for the six months ended June 30, 2016 increased $2.8 million to $5.2 million, primarily due to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on retail gas as discussed under "Operating Revenues – Energy Group" below.

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.

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 and maintains capacity on interstate pipelines to earn profit margins in the future. The wholesale energy operations utilize derivatives to mitigate price risk in order to substantially lock-in the profit margin that will ultimately be realized. However, both gas stored in inventory and pipeline capacity are not considered derivatives and are not subject to fair value accounting. Conversely, the derivatives used to reduce the risk associated with a change in the value of the inventory and pipeline capacity 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 and pipeline capacity are 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, as well as use of capacity, 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 use 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.

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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, (a) 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; (b) 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 (c) 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, 2016 and 2015, 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.

•

For the three and six months ended June 30, 2015, Economic Earnings includes losses of $3.8 million and $2.5 million, respectively, from affiliated companies that, in the periods prior to the second quarter of 2015, were not included in Economic Earnings. These adjustments are the result of a reserve for uncollectible accounts recorded by an Energenic subsidiary that owned and operated a central energy center and energy distribution system for a hotel, casino and entertainment complex in Atlantic City, New Jersey (see Note 5 to the condensed consolidated financial statements). In the periods prior to the second quarter of 2015, this charge was excluded from Economic Earnings until the total economic impact of the proceedings was realized. During the second quarter of 2015, the Company, through its investment in Energenic, reduced the carrying value of the investment in this project. As such, this charge is included in Economic Earnings for the three and six months ended June 30, 2015.

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, 2016 increased $6.8 million to $8.7 million compared with the same period in 2015, primarily as a result of the following:


•	The income contribution from on-site energy production at Marina for the three months ended June 30, 2016 increased $8.1 million to $3.8 million, primarily due to the following:


◦	$10.9 million increase due to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, which occurred in the second quarter of 2015 (see Note 5 to the condensed consolidated financial statements),


◦	$1.9 million increase due to several new renewable energy projects that began operations over the past twelve months, along with higher prices on solar renewable energy credits (SRECs) compared to the previous year as discussed in "Gross Margin - Energy Services" below.


◦	$1.3 million increase due to a settlement at Marina in 2016 (see in Note 5 to the condensed consolidated financial statements).


◦	$6.0 million decrease due to a projected decrease in the investment tax credits available on renewable energy facilities as compared to the same period in 2015. This reduction is consistent with the previously announced strategy of substantially reducing investment tax credits from solar development in 2016.


•	The income contribution from the wholesale energy operations at SJRG for the three months ended June 30, 2016 decreased $1.2 million to a net loss of $0.9 million primarily due to lower margins on daily energy trading activities, as discussed under "Gross Margin - Energy Group" below.

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Economic Earnings for the six months ended June 30, 2016 increased $4.9 million to $65.7 million compared with the same period in 2015 primarily as a result of the following:


•	The income contribution from the wholesale energy operations at SJRG for the six months ended June 30, 2016 increased $5.6 million to $10.9 million primarily due to additional capacity, as discussed under "Gross Margin - Energy Group" below.


•	The income contribution from on-site energy production at Marina for the six months ended June 30, 2016 decreased $0.1 million to $4.1 million primarily due to the following:


◦	$14.6 million decrease due to a projected decrease in the investment tax credits available on renewable energy facilities as compared to the same period in 2015. This reduction is consistent with the previously announced strategy of substantially reducing investment tax credits from solar development in 2016.


◦	$11.1 million increase due to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, which occurred in 2015 (see Note 5 to the condensed consolidated financial statements),


◦	$2.1 million increase due to several new renewable energy projects that began operations over the past twelve months, along with higher prices on SRECs compared to the previous year as discussed in "Gross Margin - Energy Services" below.


◦	$1.3 million increase due to a settlement at Marina in 2016 (see in Note 5 to the condensed consolidated financial statements)

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,
	2016			2015			2016			2015
(Loss) Income from Continuing Operations	$	(4,798	)	$	13,341		$	63,389		$	67,194
Minus/Plus:
Unrealized Mark-to-Market Losses (Gains) on Derivatives*	22,523			(15,334		)	3,911			(8,151		)
Realized Losses on Inventory Injection Hedges*	23			12			26			62
Net Loss from Affiliated Companies (A)*	—			(3,777		)	—			(2,540		)
Other (B)*	(41		)	(41		)	(82		)	(82		)
Income Taxes (C)	(9,002		)	7,656			(1,542		)	4,284
Economic Earnings	$	8,705		$	1,857		$	65,702		$	60,767

Earnings per Share from Continuing Operations	$	(0.06	)	$	0.19		$	0.86		$	0.98
Minus/Plus:
Unrealized Mark-to-Market (Gains) Losses on Derivatives*	0.30			(0.22		)	0.05			(0.12		)
Net Loss from Affiliated Companies (A)*	—			(0.05		)	—			(0.03		)
Income Taxes (C)	(0.12		)	0.11			(0.02		)	0.06
Economic Earnings per Share	$	0.12		$	0.03		$	0.89		$	0.89

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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,
	2016			2015			2016			2015
(Losses) gains on energy related commodity contracts	$	(21,371	)	$	14,685		$	(2,716	)	$	7,978
(Losses) gains on interest rate contracts	(229		)	541			(656		)	243
Total before income taxes	(21,600		)	15,226			(3,372		)	8,221
Unrealized mark-to-market (losses) gains on derivatives held by affiliated companies, before taxes*	(923		)	108			(539		)	(70		)
Total unrealized mark-to-market (losses) gains on derivatives*	(22,523		)	15,334			(3,911		)	8,151
Realized losses on inventory injection hedges*	(23		)	(12		)	(26		)	(62		)
Net Loss from Affiliated Companies (A)*	—			3,777			—			2,540
Other (B)*	41			41			82			82
Income taxes (C)	9,002			(7,656		)	1,542			(4,284		)
Total reconciling items between income (losses) from continuing operations and economic earnings	$	(13,503	)	$	11,484		$	(2,313	)	$	6,427

* Certain reclassifications have been made to the prior period numbers in these tables to conform to the current period presentation. The prior period numbers in these line items have been adjusted to be presented before income taxes.

(A) Resulting from a reserve for uncollectible accounts recorded by an Energenic subsidiary that owned and operated a central energy center and energy distribution system for a hotel, casino and entertainment complex in Atlantic City, New Jersey (see Note 5 to the condensed consolidated financial statements). In the periods prior to the second quarter of 2015, this charge was excluded from Economic Earnings until the total economic impact of the proceedings was realized. During the second quarter of 2015, the Company, through its investment in Energenic, reduced the carrying value of the investment in this project. As such, this charge is included in Economic Earnings for the three and six months ended June 30, 2015.

(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,
	2016	2015	2016	2015
Utility Throughput – decatherms (dt):
Firm Sales -
Residential	3,032	2,535	14,170	17,289
Commercial	904	673	3,087	4,351
Industrial	56	37	208	265
Cogeneration & Electric Generation	503	402	697	496
Firm Transportation -
Residential	268	265	1,276	1,792
Commercial	1,438	967	4,261	4,372
Industrial	2,931	3,069	5,984	6,017
Cogeneration & Electric Generation	1,361	1,710	2,840	3,078

Total Firm Throughput	10,493	9,658	32,523	37,660

Interruptible Sales	—	17	2	20
Interruptible Transportation	225	319	600	652
Off-System Sales	2,722	2,157	7,772	6,621
Capacity Release	17,747	13,945	33,898	28,990

Total Throughput - Utility	31,187	26,096	74,795	73,943



	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
Utility Operating Revenues:
Firm Sales -
Residential	$	34,716	$	42,376	$	152,498	$	212,585
Commercial	8,580		9,701		30,725		47,110
Industrial	431		435		1,809		3,122
Cogeneration & Electric Generation	1,435		1,483		2,181		2,288
Firm Transportation -
Residential	2,138		2,350		8,631		10,827
Commercial	6,107		4,716		18,585		18,477
Industrial	4,888		5,269		10,218		11,600
Cogeneration & Electric Generation	863		1,088		2,372		2,996

Total Firm Revenues	59,158		67,418		227,019		309,005

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	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Interruptible Sales	—			242			18			298
Interruptible Transportation	155			354			487			764
Off-System Sales	7,590			6,108			21,078			30,096
Capacity Release	1,566			1,350			7,381			2,658
Other	293			340			545			649
	68,762			75,812			256,528			343,470
Less: Intercompany Sales	(489		)	(518		)	(4,586		)	(1,646		)
Total Utility Operating Revenues	68,273			75,294			251,942			341,824
Less:
Cost of Sales - Utility (Excluding depreciation)	19,508			24,901			84,714			169,875
Conservation Recoveries*	2,032			4,861			7,133			17,124
RAC Recoveries*	2,297			2,280			4,595			4,561
EET Recoveries*	709			998			1,508			2,047
Revenue Taxes	177			208			538			787
Utility Margin**	$	43,550		$	42,046		$	153,454		$	147,430

Margin:
Residential	$	26,483		$	23,419		$	97,761		$	114,103
Commercial and Industrial	14,795			12,268			40,024			44,982
Cogeneration and Electric Generation	1,156			1,187			2,469			2,380
Interruptible	21			29			42			84
Off-System Sales & Capacity Release	750			507			2,431			2,078
Other Revenues	767			947			1,018			1,255
Margin Before Weather Normalization & Decoupling	43,972			38,357			143,745			164,882
CIP Mechanism	(1,331		)	3,185			7,932			(18,396		)
EET Mechanism	909			504			1,777			944
Utility Margin**	$	43,550		$	42,046		$	153,454		$	147,430

Degree Days:	580			415			2,796			3,340

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

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

Throughput - Gas Utility Operations -

Total gas throughput increased by 5.1 MMdts and 0.9 MMdts during the three and six months ended June 30, 2016, respectively, compared to the same periods in 2015, primarily due to a 3.8 MMdt increase in capacity release in the second quarter of 2016. The increase in capacity release volume in the second quarter was primarily related to specific releases made of Columbia pipeline capacity that did not occur in the same period in 2015. An increase in third-party supplier deliveries on Columbia pipeline to SJG’s system freed up capacity at the utility and allowed for additional capacity release during the period. Off-System Sales (OSS) volume also increased 0.6 MMdts in the second quarter of 2016, compared to the same period in 2015, due to increased opportunity to supply natural gas to gas-fired power generation facilities during the period. Total firm throughput also increased 0.8 MMdts as the result of cooler weather during the second quarter of 2016 compared to the same period in the prior year and the addition of 4,929 customers, a 1.3% increase over the last twelve months.

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For the six months ended June 30, 2016, OSS and capacity release increased 1.2 MMdts and 4.9 MMdts, respectively. Weather that was 6.4% warmer-than-normal created less demand in SJG’s service territory and more supply available for OSS and capacity release activity. Capacity release also benefited from additional third-party supplies, as previously discussed. Total firm throughput decreased 5.1 MMdts, or 13.6%, for the six months ended June 30, 2016, compared to the same period in 2015. The primary reason for the decrease was unseasonably warm weather that was 16.3% warmer during the first six months of 2016, compared to the same period in 2015. The negative impact of weather on firm throughput was partially offset by a 1.3% increase in customers compared with the same period in 2015.

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, 2016 and 2015 and the associated weather comparisons are as follows (dollars in millions):



	Three Months Ended June 30,					Six Months Ended June 30,
	2016			2015		2016		2015
Net Income Impact:
CIP – Weather Related	$	(1.1	)	$	1.7	$	2.9	$	(7.3	)
CIP – Usage Related	0.3			0.2		1.8		(3.6		)
Total Net Income Impact	$	(0.8	)	$	1.9	$	4.7	$	(10.9	)

Weather Compared to 20-Year Average	10.7% Colder			20.7% Warmer		6.4% Warmer		14.7% Colder
Weather Compared to Prior Year	39.8% Colder			12.7% Warmer		16.3% Warmer		2.4% Colder

Operating Revenues - Gas Utility Operations - Revenues decreased $7.0 million, or 9.3%, during the three months ended June 30, 2016, compared with the same period in 2015, after eliminating intercompany transactions. Total firm revenue was $8.3 million lower during the three months ended June 30, 2016, compared to the same period in the prior year. This was primarily due to SJG reducing its Basic Gas Supply Service (BGSS) rate effective October 1, 2015 by 18.6%, thereby reducing revenue by $6.8 million during the second quarter of 2016. In addition, migration of commercial customers from sales to transportation services, which do not include commodity costs, also lowered revenue during the quarter. While changes in natural gas costs and BGSS recoveries/refunds fluctuate from period to period, SJG does not profit from the sale of the commodity. Therefore, fluctuations in Utility Operating Revenue and Utility Cost of Sales, such as those discussed above, did not have an impact on SJG’s profitability.

The increase in OSS volume, discussed above under "Throughput-Gas Utility Operations," resulted in a corresponding increase in revenue, as unit sales prices remained relatively flat during the three months ended June 30, 2016, compared with the same period in 2015. While capacity release throughput increased significantly during the second quarter, lower unit prices significantly offset the impact on revenue. The impact of changes in OSS and capacity release activity does not have a material effect on the earnings of SJG, as SJG is required to return 85% of the profits of such activity to its ratepayers. Earnings from OSS and capacity release can be seen in the “Margin” table above.

Revenues decreased $89.9 million, or 26.3%, during the six months ended June 30, 2016, compared with the same period in 2015 after eliminating intercompany transactions. Total firm revenue was $82.0 million lower during the six months ended June 30, 2016 compared to the same period in the prior year, due to several factors. Firm throughput was significantly lower during the first six months of 2016, compared to the same period in the prior year, as discussed above under “Throughput-Gas Utility Operations.” The impact of this reduction in throughput lowered SJG’s recovery of natural gas costs through its BGSS mechanism by $42.8 million. In addition, SJG reduced its BGSS rate effective October 1, 2015 by 18.6%, further reducing revenue by $24.13 million during the first six months of 2016. Finally, SJG provided a $20.0 million BGSS bill credit to its residential and small commercial customers in January 2016, of which $18.7 million reduced revenue for the first six months of 2016, after consideration for sales tax. As previously discussed, these changes in natural gas costs and BGSS recoveries/refunds did not have an impact on SJG’s profitability.

Despite the increase in OSS discussed above under "Throughput - Gas Utility Operations," a 40% reduction in unit prices resulted in a net decrease of $9.0 million in OSS revenues during the six months ended June 30, 2016 compared with the same period in 2015. Capacity release revenue increased $4.7 million as a result of specific releases to Transco Zone 5 at a relatively high value, which primarily occurred during the first quarter of 2016. However, as previously discussed, the impact of changes in OSS and capacity release activity does not have a material impact on the earnings of SJG.

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Operating Revenues - Energy Group - Combined revenues for Energy Group, net of intercompany transactions, decreased $23.7 million, or 27.6%, to $62.2 million, and increased $6.7 million, or 3.6%, to $194.6 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015.

Revenues from retail gas operations at SJE, net of intercompany transactions, increased $3.5 million, or 19.0%, and decreased $4.8 million, or 8.5%, for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. Excluding the change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(6.9) million and $(5.4) million, revenues decreased $3.4 million, or 18.8%, and $10.2 million, or 18.5%, for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015.

A summary of SJE's retail gas revenue is as follows (in millions):



	Three Months Ended June 30,								Six Months Ended June 30,
	2016			2015		Change			2016			2015			Change
SJE Retail Gas Revenue	$	21.5		$	18.0	$	3.5		$	51.1		$	55.9		$	(4.8	)
Add: Unrealized Losses (Subtract: Unrealized Gains)	(6.7		)	0.2		(6.9		)	(6.5		)	(1.1		)	(5.4		)
SJE Retail Gas Revenue, Excluding Unrealized Losses (Gains)	$	14.8		$	18.2	$	(3.4	)	$	44.6		$	54.8		$	(10.2	)

The decrease in revenues for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015 was mainly due to a 26.0% and 28.1% decrease, respectively, in the average monthly New York Mercantile Exchange (NYMEX) settle price.

Revenues from retail electric operations at SJE, net of intercompany transactions, increased $7.0 million, or 20.1%, and $16.4 million, or 25.9%, for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(1.0) million and $(0.8) million, revenues increased $6.0 million, or17.2%, and $15.6 million, or 24.7%, for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015.

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,
	2016			2015			Change			2016			2015			Change
SJE Retail Electric Revenue	$	41.7		$	34.7		$	7.0		$	80.1		$	63.7		$	16.4
Add: Unrealized Losses (Subtract: Unrealized Gains)	(1.1		)	(0.1		)	(1.0		)	(0.9		)	(0.1		)	(0.8		)
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains)	$	40.6		$	34.6		$	6.0		$	79.2		$	63.6		$	15.6

The increase in revenues from retail electric operations at SJE, as defined above, for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015, was mainly due to a 4.5% and 22.0%, respectively, increase in sales volumes, partially offset by a 27.9% and 22.7%, respectively, decrease in the average monthly sales price, which was driven by a lower average Locational Marginal Price (LMP) per megawatt hour. SJE uses forward financial contracts to mitigate commodity price risk on fixed price electric contracts. In accordance with GAAP, the forward financial contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. The related customer contracts are not considered derivatives and, therefore, are not recorded in earnings until the electricity is delivered. As a result, earnings are subject to volatility as the market price of the forward financial contracts change, even when the underlying hedged value of the customer contract is unchanged. Over time, gains or losses on the sale of the fixed price electric under contract will be offset by losses or gains on the forward financial contracts, resulting in the realization of the profit margin expected when the transactions were initiated. The retail electric operations at SJE serve both fixed and market-priced customers.

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Revenues from wholesale energy operations at SJRG, net of intercompany transactions, decreased $33.8 million and $4.6 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $43.9 million and $16.7 million, revenues from the wholesale energy operations at SJRG increased $10.1 million and $12.1 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015.

A summary of revenues from wholesale energy operations at SJRG is as follows (in millions):



	Three Months Ended June 30,									Six Months Ended June 30,
	2016			2015			Change			2016		2015			Change
SJRG Revenue	$	(0.7	)	$	33.1		$	(33.8	)	$	63.7	$	68.3		$	(4.6	)
Add: Unrealized Losses (Subtract: Unrealized Gains)	29.1			(14.8		)	43.9			9.9		(6.8		)	16.7
Add: Realized Losses (Subtract: Realized Gains) on Inventory Injection Hedges	—			—			—			0.1		0.1			—
SJRG Revenue, Excluding Unrealized Losses (Gains) and Realized Losses (Gains) on Inventory Injection Hedges	$	28.4		$	18.3		$	10.1		$	73.7	$	61.6		$	12.1

The increase in revenues from the wholesale energy operations at SJRG, as defined above, for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015, was primarily due to additional capacity and revenues earned on gas supply contracts with two electric generation facilities, partially offset by a 26.0% and 28.1%, respectively, decrease in the average monthly NYMEX settle price. As discussed in Note 1 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2015, 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 $7.4 million, or 45.0%, to $23.9 million and $9.9 million, or 32.0%, to $40.9 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015.

Revenues from on-site energy production at Marina, net of intercompany transactions, increased $8.1 million, or 58.5%, to $21.8 million and $11.1 million, or 42.6%, to $37.0 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. These increases were primarily due to higher prices on solar renewable energy credits (SRECs) compared to the previous periods, an increase in SRECs transferred due to new solar projects and the revenues earned at several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the condensed consolidated financial statements). Solar revenues, net of intercompany transactions, which is included in revenues from on-site energy production above, increased $6.0 million, or 72.8%, to $14.2 million and $7.9 million, or 58.6%, to $21.5 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015.

SRECs represent the renewable energy attribute of the solar electricity generated, which can be sold to customers. Marina does not recognize revenue, or the related margin, until the SREC is certified and transferred to the customer’s electronic account. Customers may purchase SRECs to comply with solar requirements under various state renewable energy regulations. Approximately 78% of Marina’s solar production is in New Jersey.

Marina hedges a portion of its anticipated SREC production through the use of forward sales contracts. The hedged percentage of projected SREC production related to in-service assets in New Jersey is 95% and 57% for energy years ending May 31, 2017 and 2018, respectively.

Installed capacity was 194 MW and 130 MW at June 30, 2016 and 2015, respectively.

Revenues from appliance service operations at SJESP, net of intercompany transactions, did not change significantly for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015.

Margin - Gas Utility Operations - Total margin increased $1.5 million, or 3.6%, and $6.0 million, or 4.1%, for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. The rolling into base rates of Storm Hardening

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and Reliability Program (SHARP) investments of approximately $36.6 million on October 1, 2015 contributed approximately $0.8 million and $2.8 million of additional margin for the three and six months ended June 30, 2016, respectively, compared with the same period in 2015. In addition, SJG added 4,929 customers over the 12-month period ended June 30, 2016, contributing approximately $0.6 million and $2.7 million in additional margin during the three and six months ended June 30, 2016, compared with the same periods of 2015, respectively.

The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. As reflected in the margin and CIP tables above, the CIP mechanism reduced margin by $1.3 million, or $0.8 million after taxes, for the three months ended June 30, 2016, primarily due to weather that was colder than average. For the three months ended June 30, 2015, the CIP mechanism protected $3.2 million, or $1.9 million after taxes, that would have been lost due to weather that was warmer than average. The CIP mechanism protected $7.9 million, or $4.7 million after taxes, of margin for the six months ended June 30, 2016 that would have been lost due to weather that was warmer than average and lower customer usage. The CIP mechanism reduced margin by $18.4 million, or $10.9 million after taxes, for the six months ended June 30, 2015, primarily due to weather that was much colder than normal.

Gross Margin - Nonutility - 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 for the year ended December 31, 2015, 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 - Combined gross margins for Energy Group decreased $38.1 million to a loss of $16.7 million and $2.4 million to $27.8 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. These changes were primarily due to the following:

•

Gross margin from SJE’s retail gas and other operations increased $6.8 million to $8.3 million and $3.8 million to $9.6 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. Excluding the change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(6.9) million and $(5.4) million, gross margin decreased $0.1 million and $1.6 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. The three-month comparative period change was not significant. The six-month comparative period decrease is primarily due to warmer weather conditions in the first quarter of 2016 compared with the same period in 2015. 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, 2016, respectively, compared with the same periods in 2015.

•

Gross margin from SJE’s retail electric operations increased $1.7 million to $3.2 million and $1.9 million to $4.5 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(1.0) million and $(0.8) million, gross margin increased $0.7 million and $1.1 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. These increases are mainly due to increased 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, 2016, respectively, compared with the same periods in 2015.

•

Gross margin from the wholesale energy operations at SJRG decreased $46.6 million to a loss of $28.2 million and $8.1 million to $13.8 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $43.9 million and $16.7 million, gross margin for the wholesale energy operations at SJRG decreased $2.7 million and increased $8.6 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. The three-month comparative period decrease was primarily due to lower margins on daily energy trading activities. The six-month comparative period increase was due mainly to additional capacity in the first quarter of 2016 compared to the prior year.

The wholesale energy operations at SJRG expect 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, 2016, the wholesale energy operations had 9.1 Bcf of storage and 373,253 dts/day of transportation under contract.

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Gross Margin - Energy Services - Combined gross margins for Energy Services increased $9.0 million to $24.0 million and $15.2 million to $41.0 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. These changes were primarily due to the following:

•

Gross margin from on-site energy production at Marina increased $9.1 million to $22.9 million and $15.5 million to $39.0 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. Gross margin as a percentage of Operating Revenues increased 4.7 and 14.7 percentage points for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. These increases are primarily due to several new higher margin renewable energy projects that began operations over the past twelve months, along with higher prices on SRECs compared to the previous year. Also contributing to the increase were margins earned at several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the condensed consolidated financial statements).


•	Gross margin from appliance service operations at SJESP did not change significantly for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015.

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, 2016 vs. 2015			Six Months Ended June 30, 2016 vs. 2015
Gas Utility Operations	$	(1,414	)	$	(8,703	)
Nonutility:
Energy Group:
Wholesale Energy Operations	(369		)	22
Retail Gas and Other Operations	17			214
Retail Electric Operations	248			273
Subtotal Energy Group	(104		)	509
Energy Services:
On-Site Energy Production	3,571			7,405
Appliance Service Operations	(136		)	(346		)
Subtotal Energy Services	3,435			7,059
Total Nonutility	3,331			7,568
Intercompany Eliminations and Other	531			519
Total Operations Expense	$	2,448		$	(616	)

Operations - Gas utility operations expense decreased $1.4 million and $8.7 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015. The decreases primarily resulted from the operation of SJG's New Jersey Clean Energy Program and Energy Efficiency Programs. Such costs are recovered on a dollar-for-dollar basis; therefore, SJG experienced an offsetting decrease in revenue during the three and six months ended June 30, 2016, compared with the same periods in the prior year. This was due to a reduction in the approved rates used to recover such costs, as well as lower recoveries resulting from warmer weather primarily during the first quarter of 2016, as previously discussed under "Throughput-Gas Utility Operations" above.

Nonutility operations expense increased $3.3 million and $7.6 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015, primarily due to operating expenses incurred at several entities that became wholly owned by Marina as of December 31, 2015 (see Note 3 to the condensed consolidated financial statements) along with operating expenses at several new renewable energy projects that began operations over the past twelve months. Also contributing to the increase is additional personnel, governance and compliance costs incurred to support continued growth.

Maintenance - The change in maintenance expense for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015, was not significant.

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Depreciation - Depreciation increased $4.9 million and $8.7 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015, primarily due to the increased investment in property, plant and equipment by the gas utility operations of SJG and on-site energy production at Marina.

Energy and Other Taxes - The change in energy and other taxes for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015, was not significant.

Other Income and Expense - Other income increased $1.3 million for both the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015 primarily due to a settlement at Marina in 2016 as discussed in Note 5 to the condensed consolidated financial statements.

Interest Charges – Interest charges increased $0.8 million and $1.3 million for the three and six months ended June 30, 2016, respectively, compared with the same periods in 2015 primarily due to higher amounts of long-term debt outstanding at SJI and SJG, partially offset by higher capitalization of interest costs on construction at the gas utility operations of SJG during 2016. This was a result of accumulating capital investments under SJG's Accelerated Infrastructure Replacement Program (AIRP). AIRP investments are approved by the New Jersey Board of Public Utilities (BPU) to accrue interest on construction until such time as they are rolled into base rates.

Income Taxes – Income tax benefit increased $3.9 million for the three months ended June 30, 2016 compared with the same period in 2015 primarily due to a loss before income taxes incurred during the three months ended June 30, 2016 compared to income in the prior period, along with a higher effective tax rate due to a projected decrease in the investment tax credits available on renewable energy facilities at Marina. Income tax expense increased $18.7 million for the six months ended June 30, 2016 compared with the same period in 2015 primarily due to higher income before income taxes along with a higher effective tax rate due to a projected decrease in the investment tax credits available on renewable energy facilities at Marina.

Equity in Earnings (Losses) of Affiliated Companies – Equity in losses of affiliated companies decreased $15.7 million for the three months ended June 30, 2016 compared with the same period in 2015. Equity in affiliated companies went from a loss of $15.4 million to earnings of less than $0.1 million for the six months ended June 30, 2016 and 2015, respectively. The three and six month comparative period changes were primarily due to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, which occurred in the second quarter of 2015 (see Note 5 to the condensed consolidated financial statements).

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 $158.1 million and $102.1 million in the first six months of 2016 and 2015, 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 2016 produced more net cash than the same period in 2015, primarily due to improvements in working capital as a result of lower payments for gas purchases driven by warmer weather experienced during the first quarter of 2016. Also, SJI did not make a pension payment in 2016. In 2015, SJI made a $15.0 million pension contribution as a result of a decline in the discount rate and new mortality tables released at the end of 2014, both of which negatively impacted the funding status of its pension plans. 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 from investing activities, which are primarily construction projects, for the first six months of 2016 and 2015 amounted to $115.1 million and $145.7 million, respectively. We estimate the net cash outflows for investing activities for fiscal years 2016, 2017 and 2018 at SJI to be approximately $321.9 million, $383.6 million and $221.5 million, respectively. The high level of investing activities for 2016, 2017 and 2018 is due to a combination of the accelerated infrastructure investment programs and a major pipeline project to support an electric generation facility, both at SJG. Also contributing to the high level of investing activities are SJI Midstream investments in 2016 through 2018 and limited solar projects at Marina in 2016. The Company expects to use short-term borrowings under lines of credit from commercial banks and the commercial paper program to finance these investing activities as incurred. From time to time, the Company may refinance the short-term debt with long-term debt.

In support of its risk management activities, the Company is required to maintain margin accounts with selected counterparties as collateral for its forward contracts, swap agreements, options contracts and futures contracts. These margin accounts are included in Restricted Investments or Margin Account Liability, depending upon the value of the related contracts (the change in the Margin Account Liability is reflected in cash flows from Operating Activities) on the condensed consolidated balance sheets. The required amount of restricted investments changes on a daily basis due to fluctuations in the market value of the related outstanding contracts and is difficult to predict. Margin posted by the Company decreased by $7.8 million in the first six months of 2016, compared with a decrease of $12.6 million in the same period of 2015.

During the first six months of 2016 and 2015, the Company made net investments in unconsolidated affiliates of $4.6 million and $1.3 million, respectively.

In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The note bears interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. In December 2015 and February 2016, the borrower exercised each option, respectively. SJG holds a first lien security interest on land in Atlantic City as collateral against this note. In July 2016, the note was repaid in full (see Note 16 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, 2016 were as follows (in thousands):



Company	Total Facility		Usage			Available Liquidity		Expiration Date
SJG:
Commercial Paper Program/Revolving Credit Facility	$	200,000	$	14,100	(A)	$	185,900	May 2018
Uncommitted Bank Lines	10,000		—			10,000		August 2016	(C)

Total SJG	210,000		14,100			195,900

SJI:

Revolving Credit Facility	400,000		134,900		(B)	265,100		February 2018

Total SJI	400,000		134,900			265,100

Total	$	610,000	$	149,000		$	461,000

(A) Includes letters of credit outstanding in the amount of $0.8 million.

(B) Includes letters of credit outstanding in the amount of $2.8 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, 2016. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.43% and 0.96% at June 30, 2016 and 2015, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2016 and 2015 were $325.5 million and $274.3 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the six months ended June 30, 2016 and 2015 were $467.7 million and $368.1 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.

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 2016, the Company paid $12.7 million to retire outstanding debt of ACB.

In January 2016, SJG issued $61.0 million of long-term debt under a $200.0 million aggregate syndicated bank term facility. The facility is now fully drawn. The total outstanding amount under this facility as of June 30, 2016 is $200.0 million, which was reclassified to current portion of long-term debt on the condensed consolidated balance sheets as it is due within one year. SJG is evaluating alternatives, including refinancing or renewing the facility.

In May 2016, the Company issued and sold 8,050,000 shares of its common stock, par value $1.25 per share at a public offering, raising net proceeds of $203.6 million. The net proceeds from this offering were or will be used for capital expenditures primarily for regulated businesses, including infrastructure investments at its utility business.

SJI raises equity capital through its Dividend Reinvestment Plan (DRP). Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. SJI raised $10.8 million and $3.6 million of equity capital through the DRP during the six months ended June 30, 2016 and 2015, respectively. SJI does not intend to issue any more new equity capital via the DRP in 2016. Effective May 1, 2016, SJI switched to purchasing shares on the open market to fund share purchases by DRP participants.

SJI’s capital structure was as follows:



	As of June 30, 2016		As of December 31, 2015		(A)
Equity	51.1	%	41.6	%
Long-Term Debt	43.1	%	41.1	%
Short-Term Debt	5.8	%	17.3	%
Total	100.0	%	100.0	%

(A) Certain reclassifications have been made to the prior period condensed consolidated balance sheets to conform to the current period presentation, causing the amounts as of December 31, 2015 to be adjusted. See Note 1 to the condensed consolidated financial statements.

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SJI has paid dividends on its common stock for 65 consecutive years and has increased that dividend each year for the last 16 years. The Company currently looks to grow that dividend consistent with earnings growth while targeting a 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:

Environmental Remediation - Costs for remediation projects, net of recoveries from ratepayers, for the first six months of 2016 and 2015 amounted to net cash outflows of $13.4 million and $4.9 million, respectively. Total net cash outflows for remediation projects are expected to be $40.5 million, $56.0 million and $23.6 million for 2016, 2017 and 2018, respectively. As discussed in Notes 10 and 15 to the Consolidated Financial Statements in Item 8 of SJI’s 10-K for the year ended December 31, 2015, certain environmental costs are subject to recovery from and ratepayers.

Standby Letters of Credit - As of June 30, 2016, SJI provided $2.8 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. SJG provided a $0.8 million letter of credit under its revolving credit facility to support the remediation of environmental conditions at certain locations in SJG's service territory. The Company also provided $87.5 million of additional letters of credit under separate facilities outside of the revolving credit facilities to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.

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 for the year ended December 31, 2015, except for (a) construction obligations, which increased $99.0 million in total due mainly to an increase in vendor agreements regarding contractor payments at SJG; and (b) long-term debt, which increased approximately $47.9 million due to the issuance of $61.0 million of long-term debt at SJG, partially offset by a $12.7 million retirement of debt at ACB (see Note 14 to the condensed consolidated financial statements); and (c) commodity supply purchase obligations, which decreased approximately $41.8 million due to payments made during the first six months of 2016 on commitments at SJE and SJRG, partially offset by new supply deals entered into at SJRG during the second quarter of 2016.

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.

As part of the transaction involving the Energenic projects (see Note 3 to the condensed consolidated financial statements), the Company was relieved of its guarantees related to the projects in which it no longer has an ownership interest.

During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012, and as a result, Energenic subsidiaries began providing full energy services to the complex.

In June 2014 the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. As of December 31, 2015, the Energenic subsidiaries were providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries had not been able to secure a permanent or long-term energy services agreement with the new owner.

In 2015 management of the Company and Energenic evaluated the carrying value of the investment in this project and a related note receivable. Based on the inability of the Energenic subsidiaries to secure a permanent or long-term energy services agreement, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge was included in Equity in Loss of Affiliated Companies in 2015 on the condensed consolidated statements of income.

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The central energy center and energy distribution system owned by the Energenic subsidiaries was financed in part by the issuance of bonds during 2011. These bonds were collateralized primarily by certain assets of the central energy center and revenue from the energy services agreement with the hotel, casino and entertainment complex. During 2015, due to the cessation of normal business operations of the complex and the inability of the Energenic subsidiaries to meet its obligations under the bonds, the trustee for the bondholders filed suit to foreclose on certain assets of the central energy center. In November 2015 during settlement discussions, the bondholders alleged, among other things, that they were entitled to recover from Energenic itself, any amounts owed under the bonds that were not covered by the collateral, including principal, interest and attorney’s fees. The bondholders’ assertion was based on inconsistent language in the bond documents. In January 2016, Energenic and certain subsidiaries reached a multi-party settlement with the bondholders. This agreement resolves all outstanding litigation and transfers ownership of the bondholders’ collateral to the owners of the entertainment complex. The Company’s share of this settlement was $7.5 million which was accrued by Energenic as of December 31, 2015 and paid in 2016. The Company entered into agreements with its insurance carrier and external legal advisors to recover, net of legal costs, approximately $7.0 million of costs associated with the bondholder settlement discussed above, $2.1 million of which has been received as of June 30, 2016 and included in Other Income on the condensed consolidated statements of income. The remaining $4.9 million is expected to be received and recognized into income prior to the end of the year.

Management will continue to monitor the situation surrounding the complex and will evaluate the carrying value of the investment and the note receivable as future events occur.

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 gas supply and capacity management contract disputes and certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.1 million and $3.2 million related to all claims in the aggregate as of June 30, 2016 and December 31, 2015, 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 regulated and nonregulated 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 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.

The retail gas operations of SJE transact commodities on a physical basis and SJE 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. The retail electric operations of SJE use forward physical and financial contracts to mitigate commodity price risk on fixed price electric contracts. 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.

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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 unrealized (loss) gain of $(21.4) million and $14.7 million during the three months ended June 30, 2016 and 2015, respectively, and a net pre-tax unrealized (loss) gain of $(2.7) million and $8.0 million during the six months ended June 30, 2016 and 2015, respectively, which are included with realized (losses) gains 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, 2016 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	$	14,701	$	3,632	$	46	$	18,379
Prices provided by other external sources	5,730		1,395		20		7,145
Prices based on internal models or other valuation methods	24,681		6,662		174		31,517

Total	$	45,112	$	11,689	$	240	$	57,041

Liabilities
Source of Fair Value	Maturity <1 Year		Maturity 1 -3 Years		Maturity Beyond 3Years		Total
Prices actively quoted	$	14,507	$	2,065	$	17	$	16,589
Prices provided by other external sources	22,507		2,102		4		24,613
Prices based on internal models or other valuation methods	29,419		3,351		843		33,613

Total	$	66,433	$	7,518	$	864	$	74,815


•	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 22.8 million dekatherms (dts) with a weighted average settlement price of $2.90 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, along with 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 valuation methods" are 148.7 million dts with a weighted average settlement price of $(0.49) 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 30.1 million dts with a weighted average settlement price of $2.64 per dt.


•	Volumes of electric included in the table above under "Prices based on internal models or other valuation methods" are 0.2 million mwh with a weighted average settlement price of $41.25 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, 2016	$	(13,074	)
Contracts Settled During Six Months Ended June 30, 2016, Net	4,969
Other Changes in Fair Value from Continuing and New Contracts, Net	(9,669		)

Net Derivatives — Energy Related Liabilities, June 30, 2016	$	(17,774	)

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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, 2016 was $541.5 million and averaged $726.0 million during the first six months of 2016. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $4.4 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: 2015 - 14 b.p. increase; 2014 - 1 b.p. decrease; 2013 - 16 b.p. decrease; 2012 - 9 b.p. decrease; and 2011 - 33 b.p. increase. At June 30, 2016, our average interest rate on variable-rate debt was 1.45%.

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, 2016, the interest costs on $687.9 million of our long-term debt was either at a fixed rate or hedged via an interest rate derivative.

As of June 30, 2016, SJI’s active interest rate swaps were as follows:

Notional Amount

Fixed Interest Rate

Start Date

Maturity

Type

Obligor

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

12,500,000

3.530%

12/1/2006

2/1/2036

Tax-exempt

SJG

12,500,000

3.430%

12/1/2006

2/1/2036

Tax-exempt

SJG

Credit Risk - As of June 30, 2016, approximately $6.1 million, or 10.8%, of the current and noncurrent Derivatives – Energy Related Assets are transacted with two counterparties. One counterparty has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assigned to SJI in the event of default by the counterparty. The second counterparty is investment-grade rated.

As of June 30, 2016, SJRG had $87.4 million of Accounts Receivable under sales contracts. Of that total, 71.0% 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.

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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 Rule 13a-15(e) under the Exchange Act) as of June 30, 2016. 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 Rule 13a-15(f) under the Exchange Act, during the fiscal quarter ended June 30, 2016 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

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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 51.

Item 1A. Risk Factors

Other than as set forth below, there have been no material changes in our risk factors from those disclosed in Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2015.

Our stated long-term goals are based on various assumptions and beliefs that may not prove to be accurate, and we may not achieve our stated long-term goals by 2020 or at all.

Our current long-term goals are to (i) grow Economic Earnings to $150 million by 2020; (ii) improve the quality of our earnings; (iii) strengthen our balance sheet; and (iv) maintain a low-to-moderate risk profile. Management established those goals in conjunction with our board of directors based upon a number of different internal and external factors that characterize and influence our current and expected future activities. For example, these long-term goals are based on certain assumptions regarding our participation in a current project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey. However, construction on this project has not yet begun, and this project is subject to a number of regulatory approvals, including approval from the Federal Energy Regulatory Commission, which is not expected until the first quarter of fiscal 2017. The target completion date for this project has been delayed until the second half of 2018, and is subject to further delay. As a result, no assurance can be given that this project will be completed on time or at all. Further, the economy of Southern New Jersey has remained depressed relative to other regions, which could cause customer delinquencies or otherwise negatively affect achievement of our long-term earnings goals. Due to a term limit, the upcoming 2017 New Jersey gubernatorial election will result in a change in administration, which could lead to unfavorable local regulatory changes that could delay approvals, require environmental remediation or capital or other expenditures or otherwise adversely affect our results of operations, financial condition or cash flows. Other factors, assumptions and beliefs of management and our board of directors on which our long-term goals were based may also prove to differ materially from actual future results. Accordingly, we may not achieve our stated long-term goals by 2020 or at all, or our stated long-term goals may be negatively revised as a result of less than expected progress toward achieving these goals, and you are therefore cautioned not to place undue reliance on these goals.

Our business could be harmed by cybersecurity threats and related disruptions

We rely extensively on information technology systems to process transactions, transmit and store information and manage our business. Disruption or failure of our information technology systems could shut down our facilities or otherwise harm our ability to safely deliver natural gas to our customers, serve our customers effectively, or manage our assets, or otherwise materially disrupt our business.

Cyber threats are constantly evolving, increasing the difficulty of detecting and successfully defending against them. SJI has experienced such attacks in the past; however, based on information currently available to SJI, none have had a material impact on its business, financial condition, results of operations or cash flows. In response, we have invested in expanded cybersecurity systems and procedures designed to ensure the continuous and uninterrupted performance of our information technology systems and protect against unauthorized access. However, all information technology systems are potentially vulnerable to security threats, including hacking, viruses, other malicious software, and other unlawful attempts to disrupt or gain access to such systems. There is no guarantee that our cybersecurity systems and procedures will prevent or detect the unauthorized access by experienced computer programmers, hackers or others. An attack on or failure of our information technology systems could result in the unauthorized disclosure, theft, misuse or destruction of customer or employee data or business or confidential information, or disrupt the performance of our information technology systems. These events could expose us to potential liability, litigation, governmental inquiries, investigations or regulatory actions, harm our brand and reputation, diminish customer confidence, disrupt operations, and subject us to payment of fines or other penalties, legal claims by our clients and significant remediation costs.

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Item 6. Exhibits

(a) Exhibits



Exhibit No.		Description

3.1		Bylaws of South Jersey Industries, Inc. as amended and restated through April 29, 2016. (Incorporated by reference from Exhibit 3.2(ii) to the Registrant's Current Report on Form 8-K filed May 3, 2016).

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 and six months ended June 30, 2016, filed with the Securities and Exchange Commission on August 5, 2016, 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 5, 2016	By:	/s/ Stephen H. Clark
			Stephen H. Clark
			Senior Vice President & Chief Financial Officer
			(Principal Financial Officer)