Edgar Filing: SOUTH JERSEY INDUSTRIES INC

form10q.htm

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, 2011

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, 2011 there were 30,034,646 shares of the registrant’s common stock outstanding.

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		Page No.

PART I	FINANCIAL INFORMATION

Item 1.	Unaudited Condensed Consolidated Financial Statements	1
	Condensed Consolidated Statements of Income	1
	Condensed Consolidated Statements of Comprehensive Income	3
	Condensed Consolidated Statements of Cash Flows	4
	Condensed Consolidated Balance Sheets	5
	Notes to Unaudited Condensed Consolidated Financial Statements	7
	Note 1. Summary of Significant Accounting Policies	7
	Note 2. Stock-Based Compensation Plan	8
	Note 3. Discontinued Operations and Affiliations	9
	Note 4. Common Stock	11
	Note 5. Financial Instruments	11
	Note 6. Segments of Business	12
	Note 7. Rates and Regulatory Actions	14
	Note 8. Regulatory Assets & Regulatory Liabilities	15
	Note 9. Pension and Other Postretirement Benefits	16
	Note 10.Unused Lines of Credit	17
	Note 11. Commitments and Contingencies	18
	Note 12. Derivative Instruments	21
	Note 13. Fair Value of Financial Assets and Financial Liabilities	21
	Note 14. Long-Term Debt	23
	Note 15. Subsequent Events	23
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	24
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	41
Item 4.	Controls and Procedures	43

PART II	OTHER INFORMATION

Item 1.	Legal Proceedings	43
Item 1A.	Risk Factors	43
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	44
Item 6.	Exhibits	44

Signatures		44

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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,
	2011			2010

Operating Revenues:
Utility	$	64,970		$	61,185
Nonutility		95,507			90,463

Total Operating Revenues		160,477			151,648

Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility		28,042			23,781
- Nonutility		81,316			76,666
Operations		24,491			22,556
Maintenance		3,215			2,786
Depreciation		8,853			8,492
Energy and Other Taxes		2,121			1,949

Total Operating Expenses		148,038			136,230

Operating Income		12,439			15,418

Other Income and Expense		3,805			479

Interest Charges		(6,234	)		(5,664	)

Income Before Income Taxes		10,010			10,233

Income Taxes		(3,004	)		(265	)

Equity in Loss of Affiliated Companies		(761	)		(1,427	)

Income from Continuing Operations		6,245			8,541

Loss from Discontinued Operations - (Net of tax benefit)		(166	)		(101	)

Net Income	$	6,079		$	8,440

Basic Earnings Per Common Share:
Continuing Operations	$	0.209		$	0.286
Discontinued Operations		(0.006	)		(0.003	)

Basic Earnings Per Common Share	$	0.203		$	0.283

Average Shares of Common Stock Outstanding - Basic		29,953			29,873

Diluted Earnings Per Common Share:
Continuing Operations	$	0.208		$	0.285
Discontinued Operations		(0.006	)		(0.003	)

Diluted Earnings Per Common Share	$	0.202		$	0.282

Average Shares of Common Stock Outstanding - Diluted		30,037			29,975

Dividends Declared per Common Share (See Note 4)	$	0.365		$	0.660

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 INCOME (UNAUDITED)

(In Thousands Except for Per Share Data)

	Six Months Ended
	June 30,
	2011			2010


Operating Revenues:
Utility	$	239,359		$	257,242
Nonutility		253,040			223,689

Total Operating Revenues		492,399			480,931

Operating Expenses:
Cost of Sales - (Excluding depreciation)
- Utility		110,682			139,997
- Nonutility		214,896			191,694
Operations		50,185			46,036
Maintenance		6,224			5,602
Depreciation		17,505			16,734
Energy and Other Taxes		7,421			6,821

Total Operating Expenses		406,913			406,884

Operating Income		85,486			74,047

Other Income and Expense		10,377			1,503

Interest Charges		(12,215	)		(10,630	)

Income Before Income Taxes		83,648			64,920

Income Taxes		(25,514	)		(22,236	)

Equity in Loss of Affiliated Companies		(58	)		(2,575	)

Income from Continuing Operations		58,076			40,109

Loss from Discontinued Operations - (Net of tax benefit)		(549	)		(130	)

Net Income	$	57,527		$	39,979

Basic Earnings Per Common Share:
Continuing Operations	$	1.941		$	1.344
Discontinued Operations		(0.019	)		(0.005	)

Basic Earnings Per Common Share	$	1.922		$	1.339

Average Shares of Common Stock Outstanding - Basic		29,926			29,850

Diluted Earnings Per Common Share:
Continuing Operations	$	1.935		$	1.339
Discontinued Operations		(0.018	)		(0.004	)

Diluted Earnings Per Common Share	$	1.917		$	1.335

Average Shares of Common Stock Outstanding - Diluted		30,014			29,944

Dividends Declared per Common Share (See Note 4)	$	0.730		$	0.990

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,
	2011			2010

Net Income	$	6,079		$	8,440

Other Comprehensive Income (Loss), Net of Tax:*

Unrealized Gain (Loss) on Available-for-Sale Securities		51			(265	)
Unrealized (Loss) on Derivatives - Other		(50	)		(363	)
Other Comprehensive Income (Loss) of Affiliated Companies		246			(117	)

Other Comprehensive Income (Loss) - Net of Tax*		247			(745	)

Comprehensive Income	$	6,326		$	7,695

	Six Months Ended
	June 30,
	2011			2010

Net Income	$	57,527		$	39,979

Other Comprehensive Loss, Net of Tax:*

Unrealized (Loss) on Available-for-Sale Securities		(103	)		(121	)
Unrealized Gain (Loss) on Derivatives - Other		57			(266	)
Other Comprehensive (Loss) of Affiliated Companies		(833	)		(136	)

Other Comprehensive Loss - Net of Tax*		(879	)		(523	)

Comprehensive Income	$	56,648		$	39,456

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

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

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SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(In Thousands)

	Six Months Ended
	June 30,
	2011			2010

Net Cash Provided by Operating Activities	$	121,982		$	103,701

Cash Flows from Investing Activities:
Capital Expenditures		(67,778	)		(69,102	)
Net Proceeds from Sale (Purchase) of Restricted Investments in Margin Account		3,380			(6,460	)
Investment in Long-Term Receivables		(2,390	)		(1,529	)
Proceeds from Long-Term Receivables		2,418			1,047
Purchase of Company Owned Life Insurance		(3,525	)		(3,412	)
Investment in Affiliate		(21,867	)		(2,700	)
Advances on Notes Receivable - Affiliate		(24,108	)		(36,639	)
Repayment of Notes Receivable - Affiliate		38,713			2,867
Other		(5,180	)		-

Net Cash Used in Investing Activities		(80,337	)		(115,928	)

Cash Flows from Financing Activities:
Net Repayments of Lines of Credit		(55,650	)		(36,950	)
Proceeds from Issuance of Long-Term Debt		-			60,000
Payments for Issuance of Long-Term Debt		(28	)		(623	)
Dividends on Common Stock		(10,933	)		(9,858	)
Proceeds from Finance Obligation		23,425			-

Net Cash (Used in) Provided By Financing Activities		(43,186	)		12,569

Net (Decrease) Increase in Cash and Cash Equivalents		(1,541	)		342
Cash and Cash Equivalents at Beginning of Period		2,363			3,823

Cash and Cash Equivalents at End of Period	$	822		$	4,165

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,			December 31,
	2011			2010
Assets

Property, Plant and Equipment:
Utility Plant, at original cost	$	1,437,113		$	1,384,797
Accumulated Depreciation		(346,603	)		(337,993	)
Nonutility Property and Equipment, at cost		185,496			169,770
Accumulated Depreciation		(25,824	)		(23,319	)

Property, Plant and Equipment - Net		1,250,182			1,193,255

Investments:
Available-for-Sale Securities		7,116			6,720
Restricted		5,010			8,389
Investment in Affiliates		30,835			8,005

Total Investments		42,961			23,114

Current Assets:
Cash and Cash Equivalents		822			2,363
Accounts Receivable		209,707			200,773
Unbilled Revenues		19,970			72,457
Provision for Uncollectibles		(6,696	)		(8,071	)
Notes Receivable - Affiliate		8,372			1,183
Natural Gas in Storage, average cost		51,303			69,725
Materials and Supplies, average cost		3,879			3,796
Prepaid Taxes		33,028			31,384
Derivatives - Energy Related Assets		25,347			39,513
Other Prepayments and Current Assets		14,292			10,714

Total Current Assets		360,024			423,837

Regulatory and Other Noncurrent Assets:
Regulatory Assets		241,754			248,413
Derivatives - Energy Related Assets		6,612			11,556
Unamortized Debt Issuance Costs		7,263			7,583
Notes Receivables-Affiliate		101,802			126,727
Contract Receivables		12,320			12,486
Other		38,661			29,644

Total Regulatory and Other Noncurrent Assets		408,412			436,409

Total Assets	$	2,061,579		$	2,076,615

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,			December 31,
	2011			2010
Capitalization and Liabilities

Equity:
Common Stock	$	37,443		$	37,341
Premium on Common Stock		258,567			257,274
Treasury Stock (at par)		(183	)		(179	)
Accumulated Other Comprehensive Loss		(22,691	)		(21,812	)
Retained Earnings		333,134			297,473

Total South Jersey Industries, Inc. Shareholders' Equity		606,270			570,097

Long-Term Debt		426,400			340,000

Total Capitalization		1,032,670			910,097

Current Liabilities:
Notes Payable		195,037			250,687
Current Portion of Long-Term Debt		25,000			111,400
Accounts Payable		160,014			165,197
Customer Deposits and Credit Balances		18,834			10,917
Environmental Remediation Costs		21,902			27,074
Taxes Accrued		3,199			6,709
Derivatives - Energy Related Liabilities		18,619			42,297
Deferred Income Taxes - Net		1,145			3,282
Deferred Contract Revenues		4,466			5,442
Dividends Payable		10,933			-
Interest Accrued		7,183			7,259
Pension and Other Postretirement Benefits		1,217			1,217
Other Current Liabilities		5,194			9,043

Total Current Liabilities		472,743			640,524

Deferred Credits and Other Noncurrent Liabilities:
Deferred Income Taxes - Net		279,422			258,402
Investment Tax Credits		1,056			1,207
Pension and Other Postretirement Benefits		75,563			71,675
Environmental Remediation Costs		65,037			64,759
Asset Retirement Obligations		28,326			27,965
Derivatives - Energy Related Liabilities		4,214			8,641
Derivatives - Other		7,493			7,404
Regulatory Liabilities		56,069			69,248
Finance Obligation		23,425			-
Other		15,561			16,693

Total Deferred Credits and Other Noncurrent Liabilities		556,166			525,994

Commitments and Contingencies (Note 11)

Total Capitalization and Liabilities	$	2,061,579		$	2,076,615

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

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Notes to Unaudited Condensed Consolidated Financial Statements

1.	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy related products and services primarily through the following subsidiaries:

■

South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey.

■

South Jersey Resources Group, LLC (SJRG) markets wholesale natural gas storage, commodity and transportation in the mid-Atlantic, Appalachian and southern states, and owns oil, gas an mineral rights in the Marcellus Shale region of Pennsylvania.

■

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

■

South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers.

■

South Jersey Energy Service Plus, LLC (SJESP) installs residential and small commercial HVAC systems, provides plumbing services and services appliances via the sale of appliance service programs.

BASIS OF PRESENTATION — The condensed consolidated financial statements include the accounts of SJI, its wholly-owned subsidiaries and subsidiaries in which we have a controlling interest. We eliminate all significant intercompany accounts and transactions. In management’s opinion, the condensed consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI’s financial position and operating results 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 2010 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.

REVENUE BASED TAXES — SJI collects certain revenue-based energy taxes from customers. Such taxes include New Jersey State Sales Tax, Transitional Energy Facility Assessment (TEFA) 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. TEFA and PUA are included in both utility revenue and cost of sales and totaled $1.2 million and $1.1 million for the three months ended June 30, 2011 and 2010, respectively, and $5.0 million and $4.8 million for the six months ended June 30, 2011 and 2010, respectively.

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. As of June 30, 2011 and December 31, 2010, $3.2 million and $3.3 million, respectively, related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with Nonutility Property and Equipment on the condensed consolidated balance sheets.

TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of June 30, 2011 and December 31, 2010, SJI held 146,406 and 143,546 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 FASB ASC Topic 740 - “Income Taxes”. A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of the non-regulated entities are recognized on the flow through method, which may result in variations in the customary relationship between income taxes and pre-tax income for interim periods.

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NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2010 and 2011 had, or is expected to have, a material impact on the condensed consolidated financial statements.

The FASB has issued Accounting Standards Update (ASU) No. 2011-05, Comprehensive Income (Topic 220): Presentation of Comprehensive Income. This ASU allows an entity the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. In both choices, an entity is required to present each component of net income along with a total for other comprehensive income, and a total amount for comprehensive income. ASU 2011-05 eliminates the option to present the components of other comprehensive income as part of the statement of changes in stockholders’ equity. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. Management is currently evaluating the impact that the adoption of this guidance will have on the Company’s consolidated financial statements.

2.	STOCK-BASED COMPENSATION PLAN:

Under the Amended and Restated 1997 Stock-Based Compensation Plan, no more than 2,000,000 shares in the aggregate may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. The plan will terminate on January 26, 2015, unless terminated earlier by the Board of Directors. No options were granted or outstanding during the six months ended June 30, 2011 and 2010. No stock appreciation rights have been issued under the plan. During the six months ended June 30, 2011 and 2010, SJI granted 40,711 and 52,940 restricted shares to Officers and other key employees, respectively. These restricted shares vest over a three-year period and are subject to SJI achieving certain market-based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 150% of the original share units granted. During the six months ended June 30, 2011 and 2010, SJI granted 12,220 and 16,700 restricted shares to Directors, respectively. Shares issued to Directors vest over a three-year service period and contain no performance conditions. As a result, 100% of the shares granted generally vest.

See Note 2 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010 for the related accounting policy.

The following table summarizes the nonvested restricted stock awards outstanding at June 30, 2011 and the assumptions used to estimate the fair value of the awards:

	Grant Date	Shares Outstanding		Fair Value Per Share		Expected Volatility			Risk-Free Interest Rate

Officers & Key Employees -	Jan. 2009		37,748	$	39.350		28.6	%		1.20	%
	Jan. 2010		52,940	$	39.020		29.0	%		1.65	%
	Jan. 2011		40,711	$	50.940		27.5	%		1.01	%

Directors -	Jan. 2009		6,952	$	40.265		—			—
	Jan. 2010		13,360	$	37.825		—			—
	Jan. 2011		8,554	$	52.940		—			—
	Jun. 2011		1,222	$	53.170		—			—

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 three-year service period, the fair value of these awards are equal to the market value of the shares on the date of grant.

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The following table summarizes the total stock-based compensation cost for the three and six months ended June 30, 2011 and 2010:

	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010

Officers & Key Employees	$	466		$	407		$	932		$	814
Directors		327			111			457			222
Total Cost		793			518			1,389			1,036

Capitalized		(55	)		(50	)		(110	)		(101	)
Net Expense	$	738		$	468		$	1,279		$	935

As of June 30, 2011, there was $3.7 million of total unrecognized compensation cost related to nonvested share-based compensation awards granted under the restricted stock plans. That cost is expected to be recognized over a weighted average period of 2.0 years.

The following table summarizes information regarding restricted stock award activity during the six months ended June 30, 2011, excluding accrued dividend equivalents:

	Officers & Other Key Employees		Directors			Weighted Average Fair Value

Nonvested Shares Outstanding, January 1, 2011		90,688		25,390		$	39.049
Granted		40,711		12,220		$	51.407
Vested		-		(7,522	)	$	43.300
Nonvested Shares Outstanding, June 30, 2011		131,399		30,088		$	42.901

During the six months ended June 30, 2011 and 2010, SJI awarded 69,271 shares to its Officers and other key employees, which had vested at December 31, 2010, at a market value of $3.7 million, and 59,893 shares, which had vested at December 31, 2009, at a market value of $2.3 million, respectively. Also, during the six months ended June 30, 2011 and 2010, SJI awarded 12,220 and 16,700 shares to its Directors at a market value of $0.6 million for each period. The Company has a policy of issuing new shares to satisfy its obligations under these plans; therefore, there are no cash payment requirements resulting from the normal operation of this 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.

3.	DISCONTINUED OPERATIONS AND AFFILATIONS:

Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (EMI), an SJI subsidiary, which previously operated a fuel oil business. Morie is the former sand mining and processing subsidiary of EMI. EMI sold the common stock of Morie in 1996.

SJI conducts tests annually to estimate the environmental remediation costs for these properties.

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Summarized operating results of the discontinued operations for the three and six months ended June 30, were (in thousands, except per share amounts):

	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Gain (Loss) before Income Taxes:
Sand Mining	$	(157	)	$	68		$	(351	)	$	26
Fuel Oil		(99	)		(223	)		(494	)		(226	)
Income Tax Benefits		90			54			296			70
Loss from Discontinued Operations — Net	$	(166	)	$	(101	)	$	(549	)	$	(130	)
Earnings Per Common Share from
Discontinued Operations — Net:
Basic	$	(0.006	)	$	(0.003	)	$	(0.019	)	$	(0.005	)
Diluted	$	(0.006	)	$	(0.003	)	$	(0.018	)	$	(0.004	)

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

SJI and Conectiv Solutions, LLC formed Millennium Account Services, LLC in which SJI has a 50% equity interest, to provide meter reading services in southern New Jersey.

Marina and a joint venture partner formed the following entities in which Marina has a 50% equity interest:

LVE Energy Partners, LLC (LVE), which has entered into a contract to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.

Energenic – US, LLC (Energenic), which develops and operates on-site, self-contained, energy-related projects.

During the first six months of 2011 and 2010, the Company made investments in, and provided net advances to, unconsolidated affiliates of $7.3 million and $36.6 million, respectively. The purpose of these investments and advances was to cover certain project related costs of LVE (See Note 11), to provide working capital for a retail marketing operation, and to develop several landfill gas-fired electric production facilities, solar and thermal energy projects. As of June 30, 2011 and December 31, 2010, the outstanding balance on these Notes Receivable – Affiliate was $110.2 million and $127.9 million, respectively. Approximately $48.3 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 $61.9 million of these notes are unsecured, and are either non-interest bearing or accrue interest at variable rates and are to be repaid when the affiliate secures permanent financing.

SJI holds significant variable interests in these entities, but is not the primary beneficiary. Consequently, these entities are accounted for under the equity method because SJI does not have both a) the power to direct the activities of the entity that most significantly impact the entity’s economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the entity or the right to receive benefits from the entity that could potentially be significant to the entity. As of June 30, 2011, the Company had a net asset of approximately $28.9 million included in Investment in Affiliates and Other Noncurrent Liabilities on the condensed consolidated balance sheets related to Millennium, LVE and Energenic, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of June 30, 2011 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $142.1 million.

SJRG and a joint venture partner formed Potato Creek, LLC (Potato Creek) in which SJRG has a 30% equity interest. Potato Creek owns and manages the oil, gas and mineral rights of certain real estate in Pennsylvania. The mineral rights have been leased to a third-party production company (See Note 15, Subsequent Events).

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4. COMMON STOCK:

The following shares were issued and outstanding at June 30:

	2011
Beginning Balance, January 1		29,872,825
New Issues During Period:
Dividend Reinvestment Plan		40
Stock-Based Compensation Plan		81,491
Ending Balance, June 30		29,954,356

The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $1.3 million was recorded in Premium on Common Stock.

EARNINGS PER COMMON SHARE (EPS) — Basic EPS is based on the weighted-average number of common shares outstanding. The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 83,688 and 101,639 for the three months ended June 30, 2011 and 2010 respectively, and 87,980 and 94,052 shares for the six months ended June 30, 2011 and 2010, respectively. These shares relate to SJI’s restricted stock as discussed in Note 2.

DIVIDENDS DECLARED – During the first six months of 2011 and 2010, SJI declared quarterly dividends to its common shareholders that were payable in April and July of each year. In June 2010, SJI also declared its normal quarterly dividend that was payable in October 2010. During 2011, SJI did not declare its October dividend until July 2011. Consequently, Dividends Declared per Common Share on the condensed consolidated statements of income for the three and six months ended June 30, 2010 include the impact of the October 2010 dividend declaration, causing it to be higher than those declared for the three and six months ended June 30, 2011.

DIVIDEND REINVESTMENT PLAN (DRP) —The Company offers a DRP which allows participating shareholders to purchase shares of SJI common stock by the automatic reinvestment of dividends or optional purchases. Through April 2011, shares of common stock offered by the DRP have been purchased in open market transactions. Beginning in May 2011, shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock.

5.	FINANCIAL INSTRUMENTS:

RESTRICTED INVESTMENTS — In accordance with the terms of the Marina and certain SJG loan agreements, unused proceeds are required to be escrowed pending approved construction expenditures. As of both June 30, 2011 and December 31, 2010, the escrowed proceeds, including interest earned, totaled $1.3 million.

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, 2011 and December 31, 2010, the balances in these accounts totaled $3.7 million and $7.1 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at June 30, 2011 and December 31, 2010.

LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources. The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest. The carrying amounts of such loans were $10.4 million as of both June 30, 2011 and December 31, 2010. 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 $1.2 million as of both June 30, 2011 and December 31, 2010. The annual amortization to interest is not material to the Company’s condensed consolidated financial statements. The carrying amounts of these receivables approximate their fair value at June 30, 2011 and December 31, 2010.

CREDIT RISK - As of June 30, 2011, approximately $9.1 million, or 28.5%, of the current and noncurrent Derivatives – Energy Related Assets are with a single retail counterparty. This counterparty has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assigned to SJI in the event of a default by the counterparty.

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FINANCE OBLIGATION - During 2010, ACB Energy Partners LLC (ACB), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, completed construction of a combined heat and power generating facility that will serve, under an energy services agreement, a thermal plant owned by Marina. Construction period financing was provided by Marina. Due to the continuing involvement in the facility, Marina is considered the owner of the facility for accounting purposes. As a result, the Company has included $23.4 million and $20.2 million of costs to construct the facility within Nonutility Property and Equipment on the condensed consolidated balance sheets as of June 30, 2011 and December 31, 2010, respectively. In addition, the Company recorded $23.4 million of repayments from ACB to Marina on the construction loan, within the Finance Obligation on the condensed consolidated balance sheets as of June 30, 2011. Marina does not have a fixed payment obligation to ACB; as a result, the Finance Obligation is classified as a noncurrent liability. The costs to construct the facility and the repayments of the construction loan will be amortized over the term of the energy services agreement. The impact on the condensed consolidated statements of income is not significant.

OTHER FINANCIAL INSTRUMENTS – The carrying amounts of SJI’s other financial instruments approximate their fair values at June 30, 2011 and December 31, 2010.

6.	SEGMENTS OF BUSINESS:

SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. Gas Utility Operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers. Wholesale Energy Operations include SJRG’s activities. SJE is involved in both retail gas and retail electric activities. Retail Gas and Other Operations include natural gas acquisition and transportation service business lines. Retail Electric Operations consist of electricity acquisition and transportation to commercial and industrial customers. On-Site Energy Production consists of Marina’s thermal energy facility and other energy-related projects. Appliance Service Operations includes SJESP’s servicing of appliances via the sale of appliance service programs as well as on a time and materials basis, and the installation of residential and small commercial HVAC systems. The Retail Energy Operations caption includes Retail Gas and Other, Retail Electric, On-Site Energy Production and Appliance Service Operations. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices.

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Operating Revenues:
Gas Utility Operations	$	65,187		$	61,344		$	245,510		$	258,060
Wholesale Energy Operations		6,475			(4,773	)		54,746			49,668
Retail Energy Operations:
Retail Gas and Other Operations		23,042			25,781			60,284			61,615
Retail Electric Operations		54,258			58,868			114,153			90,818
On-Site Energy Production		9,863			9,180			19,651			18,530
Appliance Service Operations		4,154			4,580			8,588			9,292
Subtotal Retail Energy Operations		91,317			98,409			202,676			180,255
Corporate & Services		6,070			5,508			12,034			10,911
Subtotal		169,049			160,488			514,966			498,894
Intersegment Sales		(8,572	)		(8,840	)		(22,567	)		(17,963	)
Total Operating Revenues	$	160,477		$	151,648		$	492,399		$	480,931

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	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Operating Income (Loss):
Gas Utility Operations	$	7,065		$	9,224		$	65,558		$	57,015
Wholesale Energy Operations		1,438			(9,645	)		11,095			10,649
Retail Energy Operations:
Retail Gas and Other Operations		(59	)		(60	)		714			646
Retail Electric Operations		2,978			14,233			6,841			2,430
On-Site Energy Production		1,273			1,445			2,367			2,555
Appliance Service Operations		(232	)		(260	)		(822	)		2
Subtotal Retail Energy Operations		3,960			15,358			9,100			5,633
Corporate and Services		(24	)		481			(267	)		750
Total Operating Income	$	12,439		$	15,418		$	85,486		$	74,047

Depreciation and Amortization:
Gas Utility Operations	$	10,375		$	9,740		$	20,678		$	19,225
Wholesale Energy Operations		68			65			134			137
Retail Energy Operations:
Retail Gas and Other Operations		10			9			17			18
On-Site Energy Production		1,113			979			2,103			1,956
Appliance Service Operations		75			87			149			176
Subtotal Retail Energy Operations		1,198			1,075			2,269			2,150
Corporate and Services		178			208			339			338
Total Depreciation and Amortization	$	11,819		$	11,088		$	23,420		$	21,850

Interest Charges:
Gas Utility Operations	$	4,895		$	4,163		$	9,924		$	8,178
Wholesale Energy Operations		9			15			22			27
Retail Energy Operations:
Retail Gas and Other Operations		51			35			111			57
On-Site Energy Production		1,513			1,402			2,526			2,402
Subtotal Retail Energy Operations		1,564			1,437			2,637			2,459
Corporate and Services		689			260			1,184			317
Subtotal		7,157			5,875			13,767			10,981
Intersegment Borrowings		(923	)		(211	)		(1,552	)		(351	)
Total Interest Charges	$	6,234		$	5,664		$	12,215		$	10,630


Income Taxes:
Gas Utility Operations	$	1,065		$	2,125		$	23,111		$	20,264
Wholesale Energy Operations		858			(3,828	)		5,020			4,649
Retail Energy Operations:
Retail Gas and Other Operations		24			120			538			490
Retail Electric Operations		1,217			5,847			2,795			998
On-Site Energy Production		(864	)		(3,815	)		(7,657	)		(4,355	)
Appliance Service Operations		634			(102	)		1,633			12
Subtotal Retail Energy Operations		1,011			2,050			(2,691	)		(2,855	)
Corporate and Services		70			(82	)		74			178
Total Income Taxes	$	3,004		$	265		$	25,514		$	22,236

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	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
Property Additions:
Gas Utility Operations	$	38,638	$	26,802	$	59,076	$	58,533
Wholesale Energy Operations		6		-		30		6
Retail Energy Operations:
Retail Gas and Other Operations		2		6		15		14
On-Site Energy Production		8,590		1,929		15,297		2,164
Appliance Service Operations		132		63		133		74
Subtotal Retail Energy Operations		8,724		1,998		15,445		2,252
Corporate and Services		103		296		382		501
Total Property Additions	$	47,471	$	29,096	$	74,933	$	61,292

	June 30, 2011			December 31, 2010
Identifiable Assets:
Gas Utility Operations	$	1,492,205		$	1,468,635
Wholesale Energy Operations		225,022			237,978
Retail Energy Operations:
Retail Gas and Other Operations		25,426			21,532
Retail Electric Operations		34,911			37,383
On-Site Energy Production		181,084			147,064
Appliance Service Operations		20,380			18,528
Subtotal Retail Energy Operations		261,801			224,507
Discontinued Operations		466			890
Corporate and Services		100,763			168,788
Intersegment Assets		(18,678	)		(24,183	)
Total Identifiable Assets	$	2,061,579		$	2,076,615

7.	RATES AND REGULATORY ACTIONS:

SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). SJG made a filing with the BPU in October 2010 requesting an extension of the Capital Investment Recovery Tracker (CIRT II). The BPU approved the CIRT II program in March 2011, allowing SJG to accelerate an additional $60.3 million of capital spending into 2011 and 2012. Under CIRT II, SJG capitalizes our return on CIRT II investments until they are recovered in rate base as utility plant in service. In June 2011, SJG filed a petition for recovery of CIRT II investments through rate base and a request to increase base rates by 0.5% in October 2011. This petition is currently pending.

In March 2011, SJG credited the accounts of its Basic Gas Supply Service (BGSS) customers with refunds totaling $21.1 million due to actual gas costs being lower than projected. In June 2011, SJG filed its annual BGSS clause and Conservation Incentive Program (CIP) filings with the BPU. These petitions request a 2.9% reduction in rates for the BGSS and a 2.5% reduction in rates for the CIP, both commencing in October 2011. Also in June 2011, SJG filed its annual Energy Efficiency Tracker (EET) petition, requesting a 0.5% increase. These petitions are currently pending.

There have been no other significant regulatory actions or changes to SJG’s rate structure since December 31, 2010. See Note 10 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010.

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8.	REGULATORY ASSETS & REGULATORY LIABILITIES:

There have been no significant changes to the nature of the Company’s regulatory assets and liabilities since December 31, 2010 which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010.

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

	June 30, 2011		December 31, 2010
Environmental Remediation Costs:
Expended - Net	$	43,817	$	39,056
Liability for Future Expenditures		82,249		87,393
Income Taxes-Flowthrough Depreciation		285		774
Deferred Asset Retirement Obligation Costs		24,550		24,247
Deferred Pension and Other Postretirement Benefit Costs		68,828		69,017
Conservation Incentive Program Receivable		2,846		12,291
Societal Benefit Costs Receivable		5,987		4,216
Premium for Early Retirement of Debt		618		699
Other Regulatory Assets		12,574		10,720

Total Regulatory Assets	$	241,754	$	248,413

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

	June 30, 2011		December 31, 2010
Excess Plant Removal Costs	$	47,843	$	48,409
Deferred Revenues - Net		4,605		20,179
Other Regulatory Liabilities		3,621		660

Total Regulatory Liabilities	$	56,069	$	69,248

DEFERRED REVENUES – NET – Over/under collections of gas costs are monitored through SJG’s BGSS clause. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. The BGSS decreased from a $20.2 million regulatory liability at December 31, 2010 to a $4.6 million regulatory liability at June 30, 2011 primarily due to the BGSS refund to customers discussed above in Note 7, partially offset by gas costs recovered from customers exceeding the actual cost of the commodity incurred during the first six months of 2011 as a result of natural gas prices remaining at very low levels.

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9.	PENSION AND OTHER POSTRETIREMENT BENEFITS:

For the three and six months ended June 30, 2011 and 2010, 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,
	2011			2010			2011			2010
Service Cost	$	946		$	854		$	1,959		$	1,713
Interest Cost		2,404			2,338			4,762			4,599
Expected Return on Plan Assets		(2,340	)		(2,258	)		(4,684	)		(4,201	)
Amortizations:
Prior Service Cost		66			78			133			140
Actuarial Loss		1,417			999			2,720			2,375
Net Periodic Benefit Cost		2,493			2,011			4,890			4,626
ERIP Costs		-			-			102			-
Capitalized Benefit Costs		(902	)		(766	)		(1,812	)		(1,754	)
Total Net Periodic Benefit Expense	$	1,591		$	1,245		$	3,180		$	2,872

	Other Postretirement Benefits
	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Service Cost	$	228		$	221		$	498		$	460
Interest Cost		820			813			1,600			1,634
Expected Return on Plan Assets		(562	)		(564	)		(1,124	)		(969	)
Amortizations:
Prior Service Credits		(88	)		(89	)		(177	)		(177	)
Actuarial Loss		434			291			827			747
Net Periodic Benefit Cost		832			672			1,624			1,695
Capitalized Benefit Costs		(297	)		(240	)		(605	)		(659	)
Total Net Periodic Benefit Expense	$	535		$	432		$	1,019		$	1,036

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

The ERIP costs reflected in the table above relate to an early retirement plan offered during 2011 to one of our business segments.

No contributions were made to the pension plans during the six-month period ended June 30, 2011. During May 2010, SJI contributed $8.0 million to its pension plans. We do not expect to make any contributions to our pension plans in 2011; however, changes in future investment performance and discount rates may ultimately result in a contribution. We also have a regulatory obligation to contribute approximately $3.6 million annually to our other postretirement benefit plans’ trusts, less costs incurred directly by us.

See Note 12 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010, for additional information related to SJI’s pension and other postretirement benefits.

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10. UNUSED LINES OF CREDIT:

Credit facilities and available liquidity as of June 30, 2011 were as follows (in thousands):

Company	Total Facility		Usage		Available Liquidity		Expiration Date

SJG:

Revolving Credit Facility	$	200,000	$	40,500	$	159,500	May 2015 (A)
Uncommitted Bank Lines		20,000		20,000		—	Various

Total SJG		220,000		60,500		159,500

SJI:

Revolving Credit Facility	$	300,000	$	207,035	$	92,965	April 2015 (B)
Term Line of Credit		30,437		30,437		—	October 2011

Total SJI		330,437		237,472		92,965

Total	$	550,437	$	297,972	$	252,465

(A)	See Note 15 - Subsequent Events.

(B)	Includes letters of credit outstanding in the amount of $102.9 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 borrowing cost, which changes daily, was 1.43% and 0.73% at June 30, 2011 and 2010, respectively. Average borrowings outstanding under these credit facilities during the six months ended June 30, 2011 and 2010 were $192.4 million and $169.4 million, respectively. The maximum amounts outstanding under these credit facilities during the six months ended June 30, 2011 and 2010 were $258.4 million and $216.5 million, respectively.

New revolving credit facilities were established by SJI and SJG in April 2011 and May 2011, respectively. The SJI facility is a $300.0 million, four-year facility provided by a syndicate of banks. The SJG facility is a $200.0 million, four-year facility, provided by the same syndicate of banks. Each facility contains 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 these covenants as of June 30, 2011. These facilities replace SJI’s $200.0 million revolving credit facility and SJG’s $100.0 million revolving credit facility and $40.0 million committed line of credit, all of which would otherwise have expired in August of 2011. The letters of credit that provide liquidity support for the variable-rate revenue bonds issued by Marina are now issued under SJI’s new revolving credit facility that expires in 2015. Consequently, these bonds, which were included in the current portion of long-term debt as of December 31, 2010, are now included in long-term debt as of June 30, 2011.

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11.	COMMITMENTS AND CONTINGENCIES:

GUARANTEES — The Company has recorded a liability of $1.9 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of June 30, 2011 for the fair value of the following guarantees:

In April 2007, SJI guaranteed certain obligations of LVE Energy Partners, LLC (LVE) an unconsolidated joint venture in which Marina has a 50% equity interest. LVE entered into a 25-year contract with a resort developer to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada. LVE began construction of the facility in 2007 and expected to provide full energy service in 2010 when the resort was originally scheduled to be completed. LVE suspended construction of the district energy system and central energy center in January 2009 after the resort developer’s August 2008 announcement that it was delaying the completion of construction of the resort due to the difficult environment in the capital markets and weak economic conditions. The resort developer had indicated that it was considering different strategies to move its project forward, including opening its project in phases and obtaining a partner, but that it was unlikely construction would resume during 2009. In May 2011, the resort developer, repeating previous disclosures, indicated again that they do not expect to resume construction on the project for three to five years. They stated that they remain committed to having a significant presence on the Las Vegas Strip as part of a long-term growth strategy and continue to view this site as a major strategic asset.

The district energy system and central energy center are being financed by LVE with debt that is non-recourse to SJI. The outstanding balance of LVE’s bank debt is approximately $220.4 million as of June 30, 2011. As a result of the construction delay, the district energy system and central energy center were not completed by the end of 2010 as originally expected. Consequently, the full amount of LVE’s debt became due and payable in December 2010. LVE intends to seek additional financing to complete the facility once construction of the resort resumes, however, as of December 31, 2010, LVE was in default under the financing agreements with the banks. The Energy Sales Agreement between LVE and the resort developer includes a payment obligation by the resort developer to pay certain fees and expenses to LVE. A portion of this payment obligation is guaranteed to LVE’s lenders by the parent of the resort developer.

In March 2011, LVE reached agreements with (a) the resort developer, that specified the payments to be made by the developer to LVE during the suspension period and provided the developer and its corporate parent with an option to purchase the assets of LVE, and (b) the banks that are financing the energy facilities to address the existing default under the financing agreements. The terms of the March 2011 agreement requires the resort developer to pay certain fees and expenses to LVE on a monthly basis beginning in March 2011 until construction of the resort resumes or until the resort developer has exercised its option to purchase the energy facilities from LVE. The monthly payments that are being paid to LVE by the resort developer are expected to be sufficient to reimburse LVE for costs to maintain the energy facilities and to cover debt service costs over time. The resort developer has provided LVE with a $6.0 million letter of credit to support its monthly payment obligation.

The banks that are financing the energy facilities have agreed not to exercise their rights under the financing agreements resulting from the event of default discussed above through December 2013, provided that no additional events of default occur. SJI and its joint venture partner have provided a total of $10.0 million in letters of credit to the banks to support LVE’s obligations, which can be drawn upon by the banks at the end of the existing agreement in December 2013 or upon the occurrence of an event of default by LVE prior to December 2013.

As of June 30, 2011, the Company had a net liability of approximately $1.6 million included in Other Noncurrent Liabilities on the condensed consolidated balance sheets related to this project, in addition to unsecured Notes Receivable – Affiliate of approximately $55.0 million due from LVE. As of June 30, 2011, SJI’s capital at risk is limited to its equity contributions, letters of credit and the unsecured notes receivable totaling approximately $69.3 million. During 2011, SJI provided support to LVE of approximately $4.9 million to cover interest and other project related costs.

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As a result of the construction delay, management has evaluated the investment in LVE and concluded that the fair value of this investment continues to be in excess of the carrying value as of June 30, 2011.

SJI has guaranteed certain performance obligations of LVE under the operating agreements between LVE and the resort developer, up to $20.0 million each year for the term of the agreement, commencing with the first year of operations. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on this guarantee.

SJI has guaranteed certain obligations of BC Landfill Energy, LLC (BCLE) and WC Landfill Energy, LLC (WCLE), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. BCLE and WCLE have entered into agreements ranging from 15-20 years with the respective county governments to lease and operate facilities that will produce electricity from landfill methane gas. Although unlikely, the maximum amount that SJI could be obligated for, in the event that BCLE and WCLE do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due, is approximately $4.2 million each year. SJI and its partner in these joint ventures have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees. SJI holds variable interests in BCLE and WCLE but is not the primary beneficiary.

As of June 30, 2011, SJI had issued $4.7 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.

CAPITAL CONTRIBUTION OBLIGATION - In February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 20 year contract with a developer to build, own and operate a central energy center and energy distribution system for a planned hotel, casino and entertainment complex in Atlantic City, New Jersey. ACR is currently providing construction energy to the complex and will provide full energy services when the complex is completed in 2012. Marina and its joint venture partner will make capital contributions to ACR that will enable ACR to a) repay $42.0 million of construction advances made by the developer and b) deposit $2.8 million in a debt service reserve fund, provided, in each case, that the developer has met certain conditions. These conditions include, among others, substantial completion of the complex and demonstration of adequate financial resources to operate the complex. Marina and its joint venture partner have also agreed to provide a $5.0 million letter of credit in 2012 to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer, provided the developer has met the conditions just outlined. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI to or on behalf of ACR.

COLLECTIVE BARGAINING AGREEMENTS — Unionized personnel represent approximately 50.0% of our workforce at June 30, 2011. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76. SJG and SJESP employees represented by the IBEW operate under a collective bargaining agreement that runs through February 2013, with the option to extend until February 2014 at the union’s election. The remaining unionized employees represented by the IAM operate under a collective bargaining agreement that expires in August 2014.

STANDBY LETTERS OF CREDIT — SJI provided $102.9 million of standby letters of credit through SJI’s revolving credit facility. Letters of credit in the amount of $62.3 million support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance Marina’s initial thermal plant project and $40.6 million were posted to enable SJE to market retail electricity and for various construction activities. The Company also provided an additional $25.2 million letter of credit under a separate facility outside of the revolving credit facility to support variable-rate demand bonds issued through the NJEDA to finance the expansion of SJG’s natural gas distribution system. As of December 31, 2010, these bonds were included in the current portion of long-term debt because this letter of credit expired during 2011. The replacement letter of credit expires in August 2015, and as a result, the related bonds are now included in long-term debt as of June 30, 2011.

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ENVIRONMENTAL REMEDIATION COSTS — SJI incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. SJI and some of its nonutility subsidiaries also recorded costs for environmental cleanup of sites where SJF previously operated a fuel oil business and Morie maintained equipment, fueling stations and storage. There have been no changes to the status of the Company’s environmental remediation efforts since December 31, 2010 as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010.

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, 2011, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 13.8 MMdts of expected future purchases of natural gas, 12.4 MMdts of expected future sales of natural gas, 1.7 MMmwh of expected future purchases of electricity and 0.1 MMmwh of expected future sales of electricity. These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives — Energy Related Assets or Derivatives — Energy Related Liabilities on the condensed consolidated balance sheets. The net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility.

The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. There have been no significant changes to the Company’s active interest rate swaps since December 31, 2010 which are described in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010.

The fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of June 30, 2011 and December 31, 2010, are as follows (in thousands):

Derivatives not designated as hedging instruments under GAAP	June 30, 2011				December 31, 2010
	Assets		Liabilities		Assets		Liabilities
Energy related commodity contracts:
Derivatives – Energy Related – Current	$	25,347	$	18,619	$	39,513	$	42,297
Derivatives – Energy Related – Non-Current		6,612		4,214		11,556		8,641
Interest rate contracts:
Derivatives - Other		—		5,639		—		5,539
Total derivatives not designated as hedging instruments under GAAP		31,959		28,472		51,069		56,477

Derivatives designated as hedging instruments under GAAP

Interest rate contracts:
Derivatives - Other		—		1,854		—		1,865
Total derivatives designated as hedging instruments under GAAP		—		1,854		—		1,865

Total Derivatives	$	31,959	$	30,326	$	51,069	$	58,342

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The effect of derivative instruments on the condensed consolidated statements of income for the three and six months ended June 30, 2011 and 2010 are as follows (in thousands):

	Three months ended June 30,						Six months ended June 30,
Derivatives in Cash Flow Hedging Relationships	2011			2010			2011			2010

Interest Rate Contracts:
Losses recognized in OCI on effective portion	$	(462	)	$	(387	)	$	(642	)	$	(314	)
Losses reclassified from accumulated OCI into income (a)	$	(377	)	$	(235	)	$	(737	)	$	(468	)
Gains or (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	2011			2010			2011		2010

Gains (losses) on energy related commodity contracts (a)	$	1,657		$	4,207		$	6,132	$	(17,917	)
(Losses) gains on interest rate contracts (b)		(250	)		(600	)		11		(838	)

Total	$	1,407		$	3,607		$	6,143	$	(18,755	)

(a) Included in Operating Revenues - Non Utility

(b) Included in Interest Charges

Net realized losses associated with SJG’s energy-related financial commodity contracts of $2.5 million and $8.2 million for the three months ended June 30, 2011 and 2010, respectively, and $7.1 million and $12.3 million for the six months ended June 30, 2011 and 2010, respectively, are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy related financial commodity contracts are deferred in Regulatory Assets or Liabilities and there is no impact to earnings.

Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on June 30, 2011, is $7.7 million. If the credit-risk-related contingent features underlying these agreements were triggered on June 30, 2011, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $2.4 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.

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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, 2011	Total		Level 1		Level 2		Level 3

Assets
Available-for-Sale Securities (A)	$	7,116	$	20	$	7,096	$	—
Derivatives – Energy Related Assets (B)		31,959		10,400		16,915		4,644
	$	39,075	$	10,420	$	24,011	$	4,644

Liabilities

Derivatives – Energy Related Liabilities (B)	$	22,833	$	6,962	$	12,989	$	2,882
Derivatives – Other (C)		7,493		—		7,493		—
	$	30,326	$	6,962	$	20,482	$	2,882

As of December 31, 2010	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	6,720	$	6,720	$	—	$	—
Derivatives – Energy Related Assets (B)		51,069		21,204		24,878		4,987
	$	57,789	$	27,924	$	24,878	$	4,987

Liabilities
Derivatives – Energy Related Liabilities (B)	$	50,938	$	19,513	$	23,275	$	8,150
Derivatives – Other (C)		7,404		—		7,404		—
	$	58,342	$	19,513	$	30,679	$	8,150

(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. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.

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

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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, 2011, there were no transfers between levels within the fair value hierarchy, including no transfers in or out of Level 3.

The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and six months ended June 30, 2011, using significant unobservable inputs (Level 3), are as follows (in thousands):

	Three Months Ended			Six Months Ended
	June 30, 2011			June 30, 2011
Balance at beginning of period	$	(616	)	$	(3,163	)
Total gains and losses (realized/unrealized) included in earnings		1,565			(586	)
Transfers in and/or out of Level 3, net		—			—
Settlements		813			5,511

Balance at June 30, 2011	$	1,762		$	1,762

Total losses for 2011 included in earnings that are attributable to the change in unrealized losses relating to those assets and liabilities still held as of June 30, 2011, is $0.6 million. These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

14.	LONG-TERM DEBT:

The Company did not issue any long-term debt during the first six months of 2011. During the first six months of 2010, SJG issued $60.0 million aggregate principal amount of its Medium Term Notes in private placements due 2026. As of both June 30, 2011 and December 31, 2010, $35.0 million remained available under this $150.0 million Medium Term Note program that was approved by the NJBPU in September 2009.

The estimated fair values of SJI’s long-term debt, including current maturities, as of June 30, 2011 and December 31, 2010, were $517.8 million and $517.0 million, respectively. The carrying amounts of SJI’s long-term debt, including current maturities, as of both June 30, 2011 and December 31, 2010, were $451.4 million. We based the estimates on interest rates available to SJI at the end of each period for debt with similar terms and maturities. The carrying amounts of SJI’s other financial instruments approximate their fair values at June 30, 2011 and December 31, 2010.

15. SUBSEQUENT EVENTS:

In July 2011, SJG began 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 will have fixed maturities which will vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes will be used for general corporate purposes. SJG intends to use the commercial paper program in tandem with its new $200 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 million.

Also in July 2011, Potato Creek entered into agreements to sell certain natural gas production assets in the Marcellus Shale region of Pennsylvania. The closing is expected to occur in the fourth quarter of 2011. Potato Creek will retain its interest in the oil, gas and minerals and will continue to earn royalties on production, consistent with an existing lease agreement. Total cash proceeds to the Company from the sale are expected to be approximately $9.0 million.

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

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

A discussion of these and other risks and uncertainties may be found in the Company’s Annual Report on Form 10-K for the year ended December 31, 2010 and in other filings made by us with the Securities and Exchange Commission (SEC). These cautionary statements should not be construed by you to be exhaustive and they are made only as of the date of this Quarterly Report on Form 10-Q, or in any document incorporated by reference, at the date of such document. While South Jersey Industries, Inc. (SJI or the Company) believes these forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. Further, SJI undertakes no obligation to update or revise any of its forward-looking statements, whether as a result of new information, future events or otherwise.

Critical Accounting Policies — Estimates and Assumptions — Management must make estimates and assumptions that affect the amounts reported in the condensed consolidated financial statements and related disclosures. Actual results could differ from those estimates. Five types of transactions presented in our condensed consolidated financial statements require a significant amount of judgment and estimation. These relate to regulatory accounting, derivatives, environmental remediation costs, pension and other postretirement employee benefit costs, and revenue recognition. A discussion of these estimates and assumptions may be found in our Form 10-K for the year ended December 31, 2010.

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, 2010. See detailed discussion concerning Regulatory Actions in Note 10 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010.

Environmental Remediation —There have been no significant changes to the status of the Company’s environmental remediation efforts since December 31, 2010. See detailed discussion concerning Environmental Remediation in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010.

RESULTS OF OPERATIONS:

SJI operates in several different reportable operating segments. Gas Utility Operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers. Wholesale Energy Operations include the activities of South Jersey Resources Group, LLC (SJRG). South Jersey Energy Company (SJE) is involved in both retail gas and retail electric activities. Retail Gas and Other Operations include natural gas acquisition and transportation service business lines. Retail Electric Operations consist of electricity acquisition and transportation to commercial and industrial customers. On-Site Energy Production consists of Marina’s thermal energy facility and other energy-related projects. Appliance Service Operations includes South Jersey Energy Service Plus, LLC (SJESP’s) servicing of appliances via the sale of appliance service programs as well as on a time and materials basis, and the installation of residential and small commercial HVAC systems. The Retail Energy Operations caption includes Retail Gas and Other, Retail Electric, On-Site Energy Production and Appliance Service Operations.

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Net Income attributable to SJI for the three months ended June 30, 2011 decreased $2.4 million, or 28.0% to $6.1 million compared to the three months ended June 30, 2010 primarily as a result of the following:

●

The income contribution from SJE for the three months ended June 30, 2011 decreased $6.8 million to $1.8 million due primarily to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on electric as discussed under Operating Revenues – Nonutility below.

●

The income contribution from Marina for the three months ended June 30, 2011 decreased $2.0 million to $0.6 million due primarily to the timing of the investment tax credit available on renewable energy facilities as compared to the prior year.

●

The income contribution from SJRG for the three months ended June 30, 2011 increased $6.7 million to $1.2 million due primarily to an increase in volumes driven by the marketing of additional Marcellus production gas.

Net Income attributable to SJI for the six months ended June 30, 2011 increased $17.6 million, or 43.9% to $57.5 million compared to the six months ended June 30, 2010 primarily as a result of the following:

●

The income contribution from Marina for the six months ended June 30, 2011 increased $7.5 million to $9.6 million due primarily to the impact of the investment tax credit available on renewable energy facilities.

●

The income contribution from SJG for the six months ended June 30, 2011 increased $4.9 million to $33.9 million due primarily to the settlement of the base rate case in September 2010.

●

The income contribution from SJE for the six months ended June 30, 2011 increased $2.7 million to $4.8 million due primarily to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on electric as discussed under Operating Revenues – Nonutility below.

●

The income contribution from SJESP for the six months ended June 30, 2011 increased $2.3 million to $2.4 million due to proceeds received from a provider of homeowner assistance services, in accordance with an agreement with the Company that gives them the exclusive right to renew the home appliance repair contracts at SJESP.

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:

●

SJRG purchases and holds natural gas in storage to earn a profit margin from its ultimate sale in the future. SJRG uses derivatives to mitigate commodity price risk in order to substantially lock-in the profit margin that will ultimately be realized. However, gas stored in inventory is accounted for at the lower of average cost or market; the derivatives used to reduce the risk associated with a change in the value of the inventory are accounted for at fair value, with changes in fair value recorded in operating results in the period of change. As a result, earnings are subject to volatility as the market price of derivatives change, even when the underlying hedged value of the inventory is unchanged. This volatility can be significant from period to period. Over time, gains or losses on sale of gas in storage will be offset by losses or gains on the derivatives, resulting in the realization of the profit margin expected when the transactions were initiated.

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●

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

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

We define Economic Earnings as: Income from continuing operations, (1) less the change in unrealized gains and plus the change in unrealized losses, as applicable and in each case after tax, on all commodity derivative transactions and the ineffective portion of interest rate derivative transactions that we are marking to market, and (2) adjusting for realized gains and losses, as applicable and in each case after tax, on all hedges attributed to inventory transactions to align them with the related cost of inventory in the period of withdrawal.

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. 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, 2011 decreased $1.3 million, or 18.3%, to $5.9 million compared with the same period in 2010, primarily as a result of the following:

●

The income contribution from Marina for the three months ended June 30, 2011 decreased $2.5 million to $1.2 million due primarily to the timing of the investment tax credit available on renewable energy facilities as compared to the prior year.

●

The income contribution from SJRG for the three months ended June 30, 2011 increased $1.5 million to $1.4 million due primarily to an increase in volumes driven by the marketing of additional Marcellus production gas.

Economic Earnings for the six months ended June 30, 2011 increased $3.0 million, or 5.7%, to $54.8 million compared with the same period in 2010, primarily as a result of the following:

●

The income contribution from Marina for the six months ended June 30, 2011 increased $5.8 million to $9.8 million due primarily to the impact of the investment tax credit available on renewable energy facilities.

●

The income contribution from SJG for the six months ended June 30, 2011 increased $4.9 million to $33.9 million due primarily to the settlement of the base rate case in September 2010.

●

The income contribution from SJRG for the six months ended June 30, 2011 decreased $9.5 million to $6.7 million due primarily to tighter spreads on our storage and transportation assets.

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

	Three months ended June 30,						Six months ended June 30,
	2011			2010			2011			2010

Income from Continuing Operations	$	6,245		$	8,541		$	58,076		$	40,109
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges		(352	)		(1,331	)		(3,297	)		11,711
Economic Earnings	$	5,893		$	7,210		$	54,779		$	51,820

Earnings per Share from Continuing Operations	$	0.21		$	0.29		$	1.94		$	1.34
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges		(0.01	)		(0.05	)		(0.11	)		0.39
Economic Earnings per Share	$	0.20		$	0.24		$	1.83		$	1.73

Non-Utility Income from Continuing Operations	$	4,626		$	5,365		$	24,160		$	11,063
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges		(352	)		(1,331	)		(3,297	)		11,711
Non-Utility Economic Earnings	$	4,274		$	4,034		$	20,863		$	22,774

Wholesale Energy Income from Continuing Operations	$	1,242		$	(5,490	)	$	7,270		$	6,601
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges		103			5,334			(554	)		9,579
Wholesale Energy Economic Earnings	$	1,345		$	(156	)	$	6,716		$	16,180

Retail Energy Income (Loss) from Continuing Operations	$	3,384		$	10,855		$	16,890		$	4,462
Minus/Plus:
Unrealized Mark-to-Market (Gains)/Losses on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges		(455	)		(6,665	)		(2,743	)		2,132
Retail Energy Economic Earnings	$	2,929		$	4,190		$	14,147		$	6,594

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2011		2010		2011		2010
Utility Throughput – dth:
Firm Sales -
Residential		2,514		2,309		13,755		13,740
Commercial		639		634		3,434		3,328
Industrial		27		24		182		172
Cogeneration & Electric Generation		434		356		554		400
Firm Transportation -
Residential		317		207		1,570		1,189
Commercial		877		809		3,636		3,450
Industrial		3,191		3,254		6,636		6,343
Cogeneration & Electric Generation		1,125		803		3,526		2,996

Total Firm Throughput		9,124		8,396		33,293		31,618

Interruptible Sales		9		40		12		43
Interruptible Transportation		372		268		1,064		854
Off-System		1,551		1,921		3,455		3,037
Capacity Release		17,504		9,203		27,659		19,392

Total Throughput - Utility		28,560		19,828		65,483		54,944

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2011		2010		2011		2010
Utility Operating Revenues:
Firm Sales -
Residential	$	34,036	$	31,845	$	148,888	$	169,360
Commercial		7,741		6,862		34,541		36,485
Industrial		574		206		2,294		2,001
Cogeneration & Electric Generation		2,692		2,273		3,501		2,684
Firm Transportation -
Residential		2,313		1,502		8,863		5,956
Commercial		3,482		3,244		13,187		11,843
Industrial		4,270		4,675		8,665		8,651
Cogeneration & Electric Generation		745		709		2,487		2,718

Total Firm Revenues		55,853		51,316		222,426		239,698

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	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010

Interruptible Sales		161			590			215			638
Interruptible Transportation		328			291			962			898
Off-System		7,314			8,622			17,448			15,546
Capacity Release		1,228			212			3,899			730
Other		303			313			560			550
		65,187			61,344			245,510			258,060
Less: Intercompany Sales		(217	)		(159	)		(6,151	)		(818	)
Total Utility Operating Revenues		64,970			61,185			239,359			257,242
Less:
Cost of Sales		28,042			23,782			110,682			139,998
Conservation Recoveries*		1,447			1,254			4,702			4,373
RAC Recoveries*		1,592			1,740			3,183			3,481
EET Recoveries*		635			359			1,144			538
Revenue Taxes		1,156			1,094			5,029			4,846
Utility Margin	$	32,098		$	32,956		$	114,619		$	104,006

Margin:
Residential	$	19,676	$	14,783	$	78,475	$	60,083
Commercial and Industrial		9,239		6,764		30,566		21,722
Cogeneration and Electric Generation		765		679		1,540		1,388
Interruptible		39		76		87		114
Off-system & Capacity Release		233		68		928		377
Other Revenues		386		755		642		991
Margin Before Weather Normalization & Decoupling		30,338		23,125		112,238		84,675
CIRT Mechanism		626		2,538		1,192		4,562
CIP Mechanism		1,040		7,250		1,014		14,692
EET Mechanism		94		43		175		77
Utility Margin	$	32,098	$	32,956	$	114,619	$	104,006

Degree Days:		376		346		2,871		2,779

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

Throughput - Utility - Total gas throughput increased 8.7 MMdts, or 44.0%, and 10.5 MMdts, or 19.2%, for the three and six months ended June 30, 2011, compared with the same periods in 2010, respectively. These increases were realized primarily in the Capacity Release markets. Capacity Release increased 8.3 MMdts in both the three and six months ended June 30, 2011, as compared with the same periods in 2010, respectively, as a result of increased opportunity for such sales. Additional capacity became available during the latter part of 2010 as capacity previously transferred out of SJG under the provisions of the Conservation Incentive Program (CIP) was returned to the utility. Firm throughput increased 0.7 MMdts, or 8.7%, and 1.7 MMdts, or 5.3%, during the three and six months ended June 30, 2011, compared to the same periods in 2010, respectively. This was primarily the result of weather that was 8.7% colder during the second quarter and 3.3% colder for the six months ended June 30, 2011, as compared with the same periods last year. In addition, the Company added 3,594 customers over the twelve month period ended June 30, 2011, which represents a growth rate of 1.0%.

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Conservation Incentive Program (CIP) - Utility - The effects of the CIP on SJG’s net income for the three and six months ended June 30, 2011 and 2010 and the associated weather comparisons were as follows ($’s in millions):

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2011			2010		2011			2010
Net Income Benefit:
CIP – Weather Related	$	1.9		$	1.9	$	1.3		$	2.3
CIP – Usage Related		(1.3	)		2.4		(0.7	)		6.4
Total Net Income Benefit	$	0.6		$	4.3	$	0.6		$	8.7

Weather Compared to 20-Year Average	29.5% warmer			37.0% warmer		3.9% warmer			6.7% warmer
Weather Compared to Prior Year	8.7% colder			28.1% warmer		3.3% colder			7.3% warmer

Operating Revenues - Utility - SJG’s revenues increased $3.8 million, or 6.2%, during the three months ended June 30, 2011 compared with the same period in the prior year, after eliminating intercompany transactions. Firm sales revenue increased $4.5 million, or 8.8%, during the second quarter of 2011 versus the second quarter of 2010, as the result of higher firm throughput. As discussed previously under the caption “Throughput-Utility,” this increase was primarily the result of weather that was 8.7% colder during the second quarter of 2011 versus the same period in 2010, and the addition of approximately 3,600 customers over the twelve month period ended June 30, 2011.

A significant increase in Capacity Release throughput during the quarter, coupled with slightly higher pricing, contributed an incremental $1.0 million to revenue during the second quarter of 2011, as compared to the same period in 2010. As previously stated under “Throughput-Utility,” this was made possible when additional capacity became available during the latter part of 2010, as capacity previously transferred out of SJG under the CIP was returned to SJG. Off-System Sales (OSS) revenue decreased $1.3 million during the second quarter of 2011 versus the second quarter of 2010, as more of the newly available capacity was directed toward capacity release than OSS. As reflected in the Margin table above, the impact of the fluctuations in both Capacity Release and OSS did not have a material impact on the earnings of the Company, as SJG is required to share 85% of the profits of such activity with the ratepayers.

SJG’s revenues decreased $17.9 million, or 7.0%, during the six months ended June 30, 2011 compared with the same period in the prior year, after eliminating intercompany transactions. Firm sales revenue decreased $17.3 million, or 7.2%, during the first six months of 2011 versus the same period in 2010, as the result of lower natural gas costs experienced during 2011 which precipitated the return of $21.1 million in the form of a customer refund in March 2011. The average cost of natural gas purchased during the first six months of 2011 was $6.26 per dt, representing an 9.3% decrease relative to the average cost of $6.90 per dt during the same period in 2010.

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

Partially offsetting the negative impact of the refund on revenues was the impact of adding approximately 3,600 customers over the last twelve months, and weather that was 3.3% colder during the first six months of 2011, as compared with the same period in 2010.

OSS revenue and capacity release revenue increased $1.9 million and $3.2 million, respectively, during the first six months of 2011 versus the same period in 2010, as both sales volume and capacity release unit prices increased. As previously stated under “Throughput-Utility,” this was made possible when additional capacity became available during the latter part of 2010, as capacity previously transferred out of SJG under the CIP was returned to SJG. As reflected in the Margin table above, the impact of the higher OSS did not have a material impact on the earnings of the Company, as SJG is required to share 85% of the profits of such activity with the ratepayers.

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Operating Revenues — Nonutility - Combined revenues for SJI’s nonutility businesses, net of intercompany transactions, increased by $5.0 million and $29.4 million, or 5.6% and 13.1%, for the three and six months ended June 30, 2011 compared with the same periods in 2010.

SJE’s revenues from retail gas, net of intercompany transactions, decreased by $2.2 million and $0.5 million, or 8.8% and 0.8%, for the three and six months ended June 30, 2011 compared with the same periods in 2010. The decrease in revenues for the quarter ending June 30 was mainly due to the loss of two large volume customers under contract in 2010 with higher fixed prices which were replaced in 2011 with several lower priced market customers. Overall volumes remained relatively flat for the comparative quarters. The decrease in revenues for the comparative six months ending June 30 was due mainly to a 10.3% decrease in the average monthly New York Mercantile Exchange (NYMEX) settle price, which was partially offset by a 10.1% increase in sales volumes. As of June 30, SJE was serving the following number of retail gas customers:

	2011		2010
Residential		6,190		7,983
Commercial & Large Volume		1,600		1,557

Sales volumes for the comparative periods were as follows (in dekatherms):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2011		2010		2011		2010

Residential		60,504		73,033		347,272		431,735
Commercial & Large Volume		4,310,361		4,301,305		9,965,528		8,934,692

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

SJE’s revenues from retail electricity, net of intercompany transactions, decreased $3.6 million, or 6.4%, and increased $25.0 million, or 29.2%, for the three and six months ended June 30, 2011 compared with the same periods in 2010. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $11.3 million and $(5.6) million, revenues increased $7.7 million and $19.4 million, or 18.0% and 22.6%, for the three and six months ended June 30, 2011, respectively. A summary of SJE’s revenues from retail electricity is as follows (in millions):

	Three Months Ended									Six Months Ended
	June 30,									June 30,
	2011			2010			Change			2011			2010		Change
SJE Retail Electric Revenue	$	52.5		$	56.1		$	(3.6	)	$	110.7		$	85.7	$	25.0
Add: Unrealized Losses (Subtract: Unrealized Gains)		(2.0	)		(13.3	)		11.3			(5.2	)		0.4		(5.6	)
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains)	$	50.5		$	42.8		$	7.7		$	105.5		$	86.1	$	19.4

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These increases were mainly due to a 25.0% and 13.3% increase in volumes and a 36.1% and 20.2% increase in the average monthly Locational Marginal Price (LMP) per megawatt hour for the three and six months ended June 30, 2011, respectively, compared with the same periods of 2010. SJE uses forward financial contracts to mitigate commodity price risk on fixed price electric contracts. In accordance with GAAP, the forward financial contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. The related customer contracts are not considered derivatives and therefore are not recorded in earnings until the electricity is delivered. As a result, earnings are subject to volatility as the market price of the forward financial contracts change, even when the underlying hedged value of the customer contract is unchanged. Over time, gains or losses on the sale of the fixed price electric under contract will be offset by losses or gains on the forward financial contracts, resulting in the realization of the profit margin expected when the transactions were initiated. SJE serves both fixed and market-priced customers.

SJRG’s revenues, net of intercompany transactions, increased $11.2 million and $ 5.1 million, for the three and six months ended June 30, 2011, respectively, compared with the same periods in 2010. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts of $8.8 million and $18.6 million, respectively, due to price volatility and adjusting for realized gains and losses on all hedges attributed to inventory transactions of $1.4 million for the six months ended June 30, 2011, to align them with the related cost of inventory in the period of withdrawal, SJRG’s revenues increased $2.4 million for the three months and decreased $12.1 million for the six months ended June 30, 2011, respectively.

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

	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2011		2010			Change			2011			2010			Change
SJRG Revenue	$	6.4	$	(4.8	)	$	11.2		$	54.6		$	49.5		$	5.1
Add: Unrealized Losses (Subtract: Unrealized Gains)		0.2		9.0			(8.8	)		(1.2	)		17.4			(18.6	)
Add: Realized Losses (Subtract: Realized Gains) on Inventory Injection Hedges		-		-			-			0.3			(1.1	)		1.4
SJRG Revenue, Excluding Unrealized Losses (Gains) and Realized Losses (Gains) on Inventory Injection Hedges	$	6.6	$	4.2		$	2.4		$	53.7		$	65.8		$	(12.1	)

The increase in revenues for the three months ended June 30, 2011 compared with the same period in 2010 was due mainly to a 44.8% increase in volumes sold and a 5.5% increase in the average monthly NYMEX settle price for the comparative quarters. The decrease in revenues for the six months ended June 30, 2011 compared with the same period in 2010 was due mainly to significantly higher margins from storage and transportation assets recognized in 2010, which was partially offset by a 14.9% increase in storage volumes sold in the first six months of 2011. As discussed in Note 1 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues – Nonutility.

Revenues for Marina increased $0.7 million, or 7.4%, and $1.1 million, or 6.0%, for the three and six months ended June 30, 2011 compared with the same period in 2010 due mainly to an increase in hot water volumetric production and slightly higher chilled and hot water rates at the thermal plant and a new solar project that came on line in the second quarter of 2011.

Revenues for SJESP decreased $0.4 million or 9.3%, and $0.7 million, or 7.6% for the three and six months ended June 30, 2011 compared with the same periods in 2010 due mainly to a decrease in customer warranty contract and residential HVAC installation sales.

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

Total margin decreased $0.9 million, or 2.6%, for the three months ended June 30, 2011, compared with the same period in 2010 primarily due to a change in the timing of profits earned through the Company’s Capital Investment Recovery Tracker (CIRT). The CIRT was approved by the BPU in April 2009 and allows the Company to accelerate certain capital spending and also earn a return of, and a return on, investment at the time the investment is made. A significant portion of revenues previously recovered through the CIRT were rolled into base rates in September 2010 resulting in decreased recoveries under the CIRT program in 2011. The impact of the base rate case effectively shifted more recoveries into the first and fourth quarters, with no impact on annual net income. The CIRT added $0.6 million of pre-tax margin in the second quarter of 2011, compared with $2.5 million in the same period of 2010.

As discussed in Note 7 to the condensed consolidated financial statements, the BPU approved a CIRT II program in March 2011. Under this program, earnings on, and recoveries of, SJG’s investments are not included in margin. However, they are reflected in both Other Income and as a reduction to interest expense until the BPU approves these earnings and recoveries being included in base rates.

The CIP protected $1.0 million of pre-tax margin in the second quarter of 2011 that would have been lost due to lower customer usage, compared with $7.3 million in the same period last year. Of these amounts, $3.2 million were related to weather variations in both periods and $(2.2) million and $4.1 million were related to other customer usage variations in 2011 and 2010, respectively. A significant portion of revenues previously recovered through the CIP were rolled into base rates in September 2010 resulting in decreased recoveries under this program in the second quarter of 2011. As noted above, the impact of the base rate case effectively shifted more recoveries into the first and fourth quarters, with no impact on annual net income.

Total margin increased $10.6 million, or 10.2% for the six months ended June 30, 2011 compared with the same period in 2010 primarily due to the base rate increase granted in September 2010, higher margins from OSS and capacity release and customer additions. The CIRT added $1.2 million of pre-tax margin in the first half of 2011, compared with $4.6 million in the same period last year. As noted above, certain revenues previously recovered through the CIRT were rolled into base rates resulting in decreased recoveries under this program in 2011.

The CIP protected $1.0 million of pre-tax margin in the first half of 2011 that would have been lost due to lower customer usage, compared with $14.7 million in the same period last year. Of these amounts, $2.2 and $3.9 million were related to weather variations and $(1.2) and $10.8 million were related to other customer usage variations in 2011 and 2010, respectively. As noted above, certain revenues previously recovered through the CIP were rolled into base rates resulting in decreased recoveries under this program in 2011.

Gross Margin — Nonutility — Gross margin for the nonutility businesses is defined as revenue less all costs that are directly related to the production, selling and delivery of the company’s products and services. These costs primarily include natural gas and electric commodity costs as well as certain payroll and related benefits. On the statements of condensed consolidated income, revenue is reflected in Operating Revenues - Nonutility and the costs are reflected in Cost of Sales - Nonutility. As discussed in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues - Nonutility.

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For the three and six months ended June 30, 2011, combined gross margins for the nonutility businesses, net of intercompany transactions, increased $0.8 million and $6.5 million to $14.6 million and $38.5 million, respectively, compared with the same periods in 2010. This increase is primarily due to the following:

●

Gross margin for SJRG increased $11.6 million and $1.2 million for the three and six months ended June 30, 2011, respectively, compared with the same periods of 2010. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts as discussed above, gross margin for SJRG increased $2.8 million and decreased $17.3 million for the three and six month comparative periods. For the three month comparative period, margins increased due mainly to a 44.8% increase in volumes driven by the marketing of additional Marcellus production gas. For the six month comparative period, margins decreased due mainly to tighter spreads attained on our storage and transportation assets which were partially offset by 53.7% increase in volumes. Storage assets allow SJRG to lock in the differential between purchasing natural gas at low current prices and selling equivalent quantities at higher future prices. Gross margin is generated via seasonal pricing differentials. While this margin will be attained over the transaction cycle, the timing of physical injections and withdraws and related hedge settlements can cause earnings fluctuations for accounting purposes due to the volatile nature of wholesale gas prices. Overall, SJRG’s contribution to margin from storage and transportation assets has decreased due to market conditions and we have begun to shed some of these assets. However, we expect to continue to add substantial margin from marketing and related opportunities in the Marcellus region, capitalizing on our established presence in the area. Future margins could fluctuate significantly due to the volatile nature of wholesale gas prices.

Storage and transportation assets under contract as of June 30 are as follows:

	2011		2010

Storage (Bcf)		8.6		12.5

Transportation (dts/day)		104,000		83,115

●

Gross Margin for Marina increased $0.1 million and $0.3 million for the three and six months ended June 30, 2011, respectively, compared with the same periods of 2010. Gross margin as a percentage of Operating Revenues decreased 2.7 percentage points and 1.4 percentage points for the three and six months ended June 30, 2011 compared with the same periods in 2010 due mainly to an increase in low-margin electric sales from Marina’s thermal plant.

●

Gross margin from SJE’s retail gas sales was essentially unchanged for the three and six months ended June 30, 2011 compared with the same periods in 2010 after excluding the change in unrealized gains and losses recorded on forward financial contracts. Gross margin as a percentage of Operating Revenues increased 1.1 percentage points and 0.6 percentage points for the three and six months ended June 30, 2011 compared with the same periods in 2010 as we replaced several low-margin customers with higher margin load.

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●

Gross margin from SJE’s retail electricity sales decreased $10.8 million and increased $5.3 million for the three and six months ended June 30, 2011, respectively, compared with the same periods of 2010. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts as discussed above, gross margin increased $0.5 million and decreased $0.3 million in the three and six months ended June 30, 2011 compared with the same periods of 2010. Excluding the impact of the unrealized gains/losses, gross margin as a percentage of Operating Revenues increased 0.5 percentage points for the three months ended June 30, 2011 compared with the same period of 2010 due mainly to lower capacity and network services costs. For the six month comparative periods, gross margin as a percentage of Operating Revenues decreased 1.0 percentage points mainly due to the first quarter usage of the large number of schools that are part of a bid won in April 2009. This is a fixed-price full requirements contract. At the time we entered into this contract, we purchased a fixed price supply contract based on historical usage information contained in the bid. During the first quarter of 2010, the schools used significantly more electricity than forecast and we were able to purchase those incremental volumes at market prices that were considerably less than the original purchase price, allowing us to recognize incremental margin. In the first quarter of 2011, the schools consumption was only slightly higher than forecast, and we purchased those incremental volumes at market prices that were much closer to the original purchase price.

●

Gross margin for SJESP decreased $0.1 million and $0.3 million, respectively, in the three and six months ended June 30, 2011 compared with the same periods in 2010 due mainly to the lower customer warranty contract sales as mentioned in Operating Revenues – Nonutility. Gross margin as a percentage of Operating Revenues decreased 0.6 percentage points and 2.3 percentage points for the three and six month comparative periods, respectively, due to higher labor and benefit costs.

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

	Three Months Ended June 30, 2011 vs. 2010			Six Months Ended June 30, 2011 vs. 2010

Utility	$	918		$	1,384
Nonutility:
Wholesale Energy		472			750
Retail Gas and Other		41			15
Retail Electricity		426			858
On-Site Energy Production		141			329
Appliance Service		(118	)		533
Total Nonutility		962			2,485
Intercompany Eliminations and Other		55			280
Total Operations	$	1,935		$	4,149

Utility operations expense increased $0.9 million and $1.4 million for the three and six months ended June 30, 2011, respectively, as compared with the same periods in 2010. This increase is due primarily to increased spending under the New Jersey Clean Energy Program and Energy Efficiency Programs, which experienced a net increase of $0.5 million and $0.9 million for the three and six months ended June 30, 2011, respectively, as compared to 2010. Such costs are recovered on a dollar-for-dollar basis; therefore, SJG experienced an offsetting increase in revenues during the period.

Nonutility operations expense increased $1.0 million and $2.5 million for the three and six months ended June 30, 2011, respectively, as compared with the same periods in 2010. The increase is primarily due to additional personnel, governance and compliance costs incurred to support continued growth.

Other changes in operations expense during 2011 were not significant.

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Other Operating Expenses — Changes in other consolidated operating expenses which consist of Maintenance, Depreciation, and Energy and Other Taxes for the three and six months ended June 30, 2011, compared with the same periods in 2010, were not significant.

Other Income and Expense - Other income and expense increased $3.3 million and $8.9 million, respectively, during the three and six months ended June 30, 2011, compared with the same periods in 2010, primarily due to a) interest income charged on notes receivable from affiliates, and b) proceeds received from a provider of homeowner assistance services, in accordance with an agreement with the Company, that gives them the exclusive right to renew the home appliance repair contracts at SJESP.

Interest Charges – Interest charges increased by $0.6 million and $1.6 million for the three and six months ended June 30, 2011, respectively, compared with the same periods in 2010, primarily due to higher short-term borrowing levels and interest rates at our non-utility businesses, primarily in support of increased project development activity, and higher levels of long-term fixed rate debt at our utility in support of increased levels of infrastructure investment.

Income Taxes – Income tax expense increased by $2.7 million and $3.3 million for the three and six months ended June 30, 2011, respectively, as compared to the same periods in the prior year. The increase for the three months ended June 30, 2011 is primarily the result of an increase in the effective tax rate from 3.0% in the three months ended June 30, 2010 to 32.5% in the three months ended June 30, 2011, while the increase for the six months ended June 30, 2011 is primarily the result of an increase in Income before Income Taxes of $18.7 million, partially offset by a decrease in the effective tax rate from 35.7% in the six months ended June 30, 2010 to 30.5% in the six months ended June 30, 2011. The changes in the effective tax rates are due to projected investment tax credits of $13.7 million available on renewable energy facilities at Marina.

Equity in Loss of Affiliated Companies – Equity in loss of affiliated companies decreased by $0.7 million and $2.5 million for the three and six months ended June 30, 2011, respectively, as compared to the same periods in 2010. This decrease in equity in loss of affiliated companies is primarily due to a decrease in unrealized losses on interest rate swaps at LVE Energy Partners, LLC (LVE) that were recognized in the first half of 2010.

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

LIQUIDITY AND CAPITAL RESOURCES:

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

Cash Flows from Operating Activities — Liquidity needs are first met with net cash provided by operating activities. Net cash provided by operating activities totaled $122.0 million and $103.7 million in the first six months of 2011 and 2010, 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 2011 produced more net cash than the same period in 2010, primarily due to higher cash collections of customer accounts receivable balances, despite a $21.1 million bill credit given to utility customers in late March 2011 and a reduction in required tax payments during 2011.

Cash Flows from Investing Activities — SJI has a continuing need for cash resources and capital, primarily to invest in new and replacement facilities and equipment. Net cash outflows for capital expenditures, which are primarily construction projects, for the first six months of 2011 and 2010 amounted to $67.8 million and $69.1 million, respectively. We estimate the net cash outflows for SJI for construction projects for fiscal years 2011, 2012 and 2013 at SJI and its unconsolidated affiliates to be approximately $150.8 million, $120.4 million and $68.0 million, respectively. For capital expenditures, including those under SJG’s CIRT, the Company will use short-term borrowings to finance capital expenditures as incurred. From time to time, the Company will refinance the short-term debt incurred to support capital expenditures with long-term debt.

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In support of its risk management activities, the Company is required to maintain margin accounts with selected counterparties as collateral for its forward contracts, swap agreements, options contracts and futures contracts. These margin accounts are included in Restricted Investments or Margin Account Liability, depending upon the value of the related contracts (the change in the Margin Account Liability is reflected in cash flows from Operating Activities) on the condensed consolidated balance sheets. The required amount of restricted investments changes on a daily basis due to fluctuations in the market value of the related outstanding contracts and are difficult to predict. Margin posted by the Company decreased by $3.4 million in the first six months of 2011, compared with an increase of $6.5 million in the same period of 2010.

During the six months ended June 30, 2011 and 2010, the Company made investments in, and provided net advances to unconsolidated affiliates of $7.3 million and $36.6 million, respectively. The purpose of these investments and advances was to cover certain project related costs of LVE Energy Partners, LLC (See Commitments and Contingencies), to provide working capital for a retail marketing operation, and to develop several landfill gas-fired electric production facilities, solar and thermal energy projects.

Cash Flows from Financing Activities — Short-term borrowings under 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, 2011 were as follows (in thousands):

Company	Total Facility		Usage		Available Liquidity		Expiration Date

SJG:

Revolving Credit Facility	$	200,000	$	40,500	$	159,500	May 2015 (A)
Uncommitted Bank Lines		20,000		20,000		—	Various

Total SJG		220,000		60,500		159,500

SJI:
Revolving Credit Facility	$	300,000	$	207,035	$	92,965	April 2015 (B)
Term Line of Credit		30,437		30,437		—	October 2011

Total SJI		330,437		237,472		92,965

Total	$	550,437	$	297,972	$	252,465

(A)

See Note 15 - Subsequent Events to the condensed consolidated financial statements.

(B)

Includes letters of credit outstanding in the amount of $102.9 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. 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, 2011. Borrowings under these credit facilities are at market rates. The weighted average borrowing cost, which changes daily, was 1.43% and 0.73% at June 30, 2011 and 2010, 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.

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SJI supplements its operating cash flow 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), 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 March and June 2010, SJG issued $15.0 million and $45 million aggregate principal amounts, respectively, of its MTNs under private placements. No other long-term debt was issued during the six months ended June 30, 2011 and 2010.

SJI’s capital structure was as follows:

	As of June 30, 2011			As of December 31, 2010

Equity		48.4	%		44.8	%
Long-Term Debt		36.0			35.5
Short-Term Debt		15.6			19.7
Total		100.0	%		100.0	%

SJI has paid dividends on its common stock for 59 consecutive years and has increased that dividend each year for the last ten years. The Company currently looks to grow that dividend by at least 6% to 7% per year and has a targeted payout ratio of between 50% and 60%. 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.

During the first six months of 2011 and 2010, SJI declared quarterly dividends to its common shareholders that were payable in April and July of each year. In June 2010, SJI also declared its normal quarterly dividend that was payable in October 2010. During 2011, SJI did not declare its dividend payable in October until the third quarter. Consequently, Dividends Declared per Common Share for the three and six months ended June 30, 2010 includes the impact of the October dividend, while Dividends Declared per Common share for the three months ended June 30, 2011 does not include the impact of the dividend to be paid October 2011.

During the six months ended June 30, 2011, the Company received $23.4 million of repayments from ACB Energy Partners, LLC (ACB) to Marina on a construction loan provided by Marina as discussed in Note 5 to the condensed consolidated financial statements.

COMMITMENTS AND CONTINGENCIES:

SJI has a continuing need for cash resources and capital, primarily to invest in new and replacement facilities and equipment, and for environmental remediation costs. Cash outflows for capital expenditures for the first six months of 2011 and 2010 amounted to $67.8 million and $69.1 million, respectively. Management estimates the net cash outflows for SJI for construction projects for 2011, 2012 and 2013 at SJI and its unconsolidated affiliates to be approximately $150.8 million, $120.4 million and $68.0 million, respectively. Costs for remediation projects, net of insurance reimbursements, for the first six months of 2011 and 2010 amounted to net cash outflows of $7.8 million and net cash outflows of $1.5 million, respectively. Total cash outflows for remediation projects are expected to be $20.1 million, $12.8 million and $10.6 million for 2011, 2012 and 2013, respectively. As discussed in Notes 10 and 15 to the Consolidated Financial Statements in Item 8 of SJI’s 10-K as of December 31, 2010, certain environmental costs are subject to recovery from insurance carriers and ratepayers.

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SJI provided $102.9 million of standby letters of credit through SJI’s revolving credit facility. Letters of credit in the amount of $62.3 million support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance Marina’s initial thermal plant project and $40.6 million were posted to enable SJE to market retail electricity and for various construction activities. The Company also provided an additional $25.2 million letter of credit under a separate facility outside of the revolving credit facility to support variable-rate demand bonds issued through the NJEDA to finance the expansion of SJG’s natural gas distribution system. As of December 31, 2010, these bonds were included in the current portion of long-term debt because this letter of credit expired during 2011. The replacement letter of credit expires in August 2015, and as a result, the related bonds are now included in long-term debt as of June 30, 2011.

In the normal course of business, SJG and SJRG have entered into long-term contracts for natural gas supplies. SJRG has committed to purchase a minimum of 283,100 dts/d and up to 700,000 dts/d of natural gas, from various suppliers, for terms ranging from three to ten years at index-based prices. SJG has committed to purchase a minimum of 6,250 dts/d and up to 25,000 dts/d of natural gas, from one supplier, for a term of eight years at index-based prices.

There were no significant changes to the Company’s contractual obligations described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K as of December 31, 2010, except for commodity supply purchase obligations which decreased by approximately $146.3 million in total since December 31, 2010, due to payments made during the first six months of 2011 on commitments at SJE and SJRG.

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

The Company has recorded a liability of $1.9 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of June 30, 2011 for the fair value of the following guarantees:

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In March 2011, LVE reached agreements with (a) the resort developer, that specified the payments to be made by the developer to LVE during the suspension period and provided the developer and its corporate parent with an option to purchase the assets of LVE, and (b) the banks that are financing the energy facilities to address the existing default under the financing agreements. The terms of the March 2011 agreement requires the resort developer to pay certain fees and expenses to LVE on a monthly basis beginning in March 2011 until construction of the resort resumes or until the resort developer has exercised its option to purchase the energy facilities from LVE. The monthly payments that are being paid to LVE by the resort developer are expected to be sufficient to reimburse LVE for costs to maintain the energy facilities and to cover debt service costs over-time. The resort developer has provided LVE with a $6.0 million letter of credit to support its monthly payment obligation.

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Capital Contribution Obligation - In February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 20 year contract with a developer to build, own and operate a central energy center and energy distribution system for a planned hotel, casino and entertainment complex in Atlantic City, New Jersey. ACR is currently providing construction energy to the complex and will provide full energy services when the complex is completed in 2012. Marina and its joint venture partner will make capital contributions to ACR that will enable ACR to a) repay $42.0 million of construction advances made by the developer and b) deposit $2.8 million in a debt service reserve fund, provided, in each case, that the developer has met certain conditions. These conditions include, among others, substantial completion of the complex and demonstration of adequate financial resources to operate the complex. Marina and its joint venture partner have also agreed to provide a $5.0 million letter of credit in 2012 to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer, provided the developer has met the conditions just outlined. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI to or on behalf of ACR.

Pending Litigation — SJI is subject to claims arising in the ordinary course of business and other legal proceedings. We accrue liabilities related to claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. SJI has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. Management does not currently anticipate the disposition of any known claims to have a material adverse effect on SJI’s financial position, results of operations or liquidity.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

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

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

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SJI has entered into certain contracts to buy, sell, and transport natural gas and to buy and sell retail electricity. For those derivatives not designated as hedges, we recorded the net unrealized pre-tax gain of $1.7 million and $4.2 million in earnings during the three months ended June 30, 2011 and 2010, respectively, and the net unrealized pre-tax gain of $6.1 million and the net unrealized pre-tax loss of $17.9 million during the six months ended June 30, 2011 and 2010, respectively, which are included with realized gains and losses in Operating Revenues — Nonutility. The fair value and maturity of these energy-related contracts determined under the mark-to-market method as of June 30, 2011 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	$	8,515	$	1,861	$	24	$	10,400
Prices provided by other external sources		13,006		3,772		137		16,915
Prices based on internal models or other valuable methods		3,826		818		—		4,644

Total	$	25,347	$	6,451	$	161	$	31,959

Liabilities
Source of Fair Value	Maturity < 1 Year		Maturity 1 -3 Years		Maturity Beyond 3Years		Total
Prices actively quoted	$	6,082	$	878	$	2	$	6,962
Prices provided by other external sources		10,519		2,465		5		12,989
Prices based on internal models or other valuable methods		2,018		864		—		2,882

Total	$	18,619	$	4,207	$	7	$	22,833

NYMEX (New York Mercantile Exchange) is the primary national commodities exchange on which natural gas is traded. Basis represents the price of a NYMEX natural gas futures contract adjusted for the difference in price for delivering the gas at another location. Contracted volumes of our NYMEX contracts are 3.4 million decatherms (dts) with a weighted-average settlement price of $5.22 per dt. Contracted volumes of our basis contracts are 18.7 million dts with a weighted average settlement price of $0.50 per dt. Contracted volumes of electric are 1.7 million mwh with a weighted average settlement price of $54.70 per mwh.

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

Net Derivatives — Energy Related Assets, January 1, 2011	$	131
Contracts Settled During Six Months Ended June 30, 2011, Net		6,908
Other Changes in Fair Value from Continuing and New Contracts, Net		2,087

Net Derivatives — Energy Related Assets June 30, 2011	$	9,126

Interest Rate Risk — Our exposure to interest-rate risk relates primarily to short-term, variable-rate borrowings. Short-term, variable-rate debt outstanding at June 30, 2011 was $195.0 million and averaged $192.4 million during the first six months of 2011. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $1.2 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: 2010 – 13 b.p. increase; 2009 – 29 b.p. decrease; 2008 – 397 b.p. decrease; 2007 – 45 b.p. decrease; and 2006 – 67 b.p. increase. For June 2011, our average interest rate on variable-rate debt was 1.47%.

We issue long-term debt either at fixed rates or use interest rate derivatives to limit our exposure to changes in interest rates on variable-rate, long-term debt. As of June 30, 2011, the interest costs on all but $7.1 million of our long-term debt was either at a fixed-rate or hedged via an interest rate derivative. Consequently, interest expense on existing long-term debt is not significantly impacted by changes in market interest rates.

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As of June 30, 2011, SJI’s active interest rate swaps were as follows:

Amount		Fixed Interest Rate			Start Date	Maturity	Type	Obligor
$	3,900,000		4.795	%	12/01/2004	12/01/2014	Taxable	Marina
$	8,000,000		4.775	%	11/12/2004	11/12/2014	Taxable	Marina
$	20,000,000		4.080	%	11/19/2001	12/01/2011	Tax-exempt	Marina
$	14,500,000		3.905	%	03/17/2006	01/15/2026	Tax-exempt	Marina
$	500,000		3.905	%	03/17/2006	01/15/2026	Tax-exempt	Marina
$	330,000		3.905	%	03/17/2006	01/15/2026	Tax-exempt	Marina
$	7,100,000		4.895	%	02/01/2006	02/01/2016	Taxable	Marina
$	12,500,000		3.430	%	12/01/2006	02/01/2036	Tax-exempt	SJG
$	12,500,000		3.430	%	12/01/2006	02/01/2036	Tax-exempt	SJG

Credit Risk - As of June 30, 2011, approximately $9.1 million, or 28.5%, of the current and noncurrent Derivatives – Energy Related Assets are with a single retail counterparty. This counterparty has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assignable to SJI in the event of a default by the counterparty.

As of June 30, 2011, SJRG had $81.3 million of Accounts Receivable under sales contracts. Of that total, 80.7% were with regulated utilities or companies rated investment-grade or guaranteed by an investment-grade-rated parent or were with companies where we have a collateral arrangement or insurance coverage. The remainder of the Accounts Receivable were within approved credit limits.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

The Company’s management, with the participation of its chief executive officer and chief financial officer, evaluated the effectiveness of the design and operation of the Company’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of June 30, 2011. Based on that evaluation, the Company’s chief executive officer and chief financial officer concluded that the disclosure controls and procedures employed at the Company are effective.

Changes in Internal Control Over Financial Reporting

There has not been any change in the Company’s internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act, during the fiscal quarter ended June 30, 2011 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

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 41.

Item 1A. Risk Factors

There have been no material changes to our risk factors from those disclosed in Part I, Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2010.

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

Issuer Purchases of Equity Securities

The following table presents information about purchases by SJI of its own common stock during the three months ended June 30, 2011:

Period	Total Number of Shares Purchased1		Average Price Paid Per Share1		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs2		Maximum Number of Shares that MayYet be Purchased Under the Plans or Programs2

April 2011		22,168	$	57.08		—		—
May 2011		1,536	$	55.73		—		—
June 2011		1,222	$	53.17		—		—
Total		24,926				—		—

1 The total number of shares purchased and the average price paid per share represent shares purchased in open market transactions under the South Jersey Industries Dividend Reinvestment Plan (the DRP) by the administrator of the DRP.

2 On September 22, 2008, SJI publicly announced a share repurchase program under which the Company can purchase up to 5% of its currently outstanding common stock over the next four years. As of June 30, 2011, no shares have been purchased under this program.

Item 6. Exhibits

(a) Exhibits

Exhibit No.		Description

31.1		Certification of Chief Executive Officer Pursuant to Rule 13a-14(a) of the Exchange Act.

31.2		Certification of Chief Financial Officer Pursuant to Rule 13a-14(a) of the Exchange Act.

32.1		Certification of Chief Executive Officer Pursuant to Rule 13a-14(b) of the Exchange Act as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code).

32.2		Certification of Chief Financial Officer Pursuant to Rule 13a-14(b) of the Exchange Act as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code).

101		The following financial statements from South Jersey Industries’ Quarterly Report on Form 10-Q for the three and six months ended June 30, 2011, filed with the Securities and Exchange Commission on August 8, 2011, 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.

SIGNATURES

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

	SOUTH JERSEY INDUSTRIES, INC.
	(Registrant)

Dated: August 8, 2011	By:	/s/ Edward J. Graham
		Edward J. Graham
		Chairman, President & Chief Executive Officer

Dated: August 8, 2011	By:	/s/ David A. Kindlick
		David A. Kindlick
		Vice President & Chief Financial Officer