10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10-Q

(Mark one)

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

For the quarterly period ended September 30, 2013

OR

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

For the transition period from ________________ to ________________

Commission File Number 000-22211

SOUTH JERSEY GAS COMPANY

(Exact name of registrant as specified in its charter)

New Jersey	21-0398330
(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)

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

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 o	Accelerated filer o
Non-accelerated filer x (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 November 1, 2013 there were 2,339,139 shares of the registrant’s common stock outstanding. All common shares are owned by South Jersey Industries, Inc., the parent company of South Jersey Gas Company.

TABLE OF CONTENTS

		Page No.
PART I	FINANCIAL INFORMATION
Item 1.	Financial Statements	3
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	22
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	29
Item 4.	Controls and Procedures	31
PART II	OTHER INFORMATION
Item 1.	Legal Proceedings	31
Item 1A.	Risk Factors	31
Item 6.	Exhibits	32
Signatures		33

2

SOUTH JERSEY GAS COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

(In Thousands)

	Three Months Ended
	September 30,
	2013			2012
Operating Revenues	$	59,674		$	54,251
Operating Expenses:
Cost of Sales (Excluding depreciation)	24,717			21,053
Operations	18,613			17,536
Maintenance	3,353			3,570
Depreciation	8,654			7,975
Energy and Other Taxes	1,052			1,167
Total Operating Expenses	56,389			51,301
Operating Income	3,285			2,950
Other Income and Expense	764			1,703
Interest Charges	(2,629		)	(3,872		)
Income Before Income Taxes	1,420			781
Income Taxes	(471		)	(258		)
Net Income	$	949		$	523

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

3

	Nine Months Ended
	September 30,
	2013			2012
Operating Revenues	$	300,308		$	292,864
Operating Expenses:
Cost of Sales (Excluding depreciation)	128,427			127,959
Operations	62,132			56,677
Maintenance	10,140			10,133
Depreciation	25,128			23,010
Energy and Other Taxes	5,332			5,815
Total Operating Expenses	231,159			223,594
Operating Income	69,149			69,270
Other Income and Expense	3,024			4,482
Interest Charges	(8,379		)	(11,832		)
Income Before Income Taxes	63,794			61,920
Income Taxes	(23,511		)	(23,122		)
Net Income	$	40,283		$	38,798

4

SOUTH JERSEY GAS COMPANY

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(In Thousands)

	Three Months Ended
	September 30,
	2013		2012
Net Income	$	949	$	523
Other Comprehensive Gain - Net of Tax: *
Unrealized Gain on Available-for-Sale Securities	221		205
Unrealized Gain on Derivatives - Other	7		7
Other Comprehensive Gain - Net of Tax *	228		212
Comprehensive Income	$	1,177	$	735

	Nine Months Ended
	September 30,
	2013			2012
Net Income	$	40,283		$	38,798
Other Comprehensive (Loss) Gain   - Net of Tax: *
Unrealized (Loss) Gain on Available-for-Sale Securities	(76		)	420
Unrealized Gain on Derivatives - Other	21			21
Other Comprehensive (Loss) Gain  - Net of Tax *	(55		)	441
Comprehensive Income	$	40,228		$	39,239

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

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

5

SOUTH JERSEY GAS COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

(In Thousands)

	Nine Months Ended
	September 30,
	2013			2012
Net Cash Provided by Operating Activities	$	109,974		$	51,006
Cash Flows from Investing Activities:
Capital Expenditures	(118,383		)	(114,886		)
Net (Purchase) Sale of Restricted Investments in Margin Accounts	(809		)	641
Investment in Long-Term Receivables	(5,012		)	(4,178		)
Proceeds from Long-Term Receivables	5,376			5,217
Net Cash Used in Investing Activities	(118,828		)	(113,206		)
Cash Flows from Financing Activities:
Net Borrowing from Short-Term Credit Facilities	7,900			11,300
Proceeds from Issuance of Long-Term Debt	—			85,000
Principal Repayments of Long-Term Debt	(25,000		)	(35,000		)
Premium for Early Retirement of Debt	—			(700		)
Payments for Issuance of Long-Term Debt	(30		)	(936		)
Additional Investment by Shareholder	25,000			—
Net Cash Provided by Financing Activities	7,870			59,664
Net Decrease in Cash and Cash Equivalents	(984		)	(2,536		)
Cash and Cash Equivalents at Beginning of Period	2,678			3,504
Cash and Cash Equivalents at End of Period	$	1,694		$	968

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

6

SOUTH JERSEY GAS COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

(In Thousands)

	September 30, 2013			December 31, 2012
Assets
Property, Plant and Equipment:
Utility Plant, at original cost	$	1,776,502		$	1,658,790
Accumulated Depreciation	(388,511		)	(373,199		)
Property, Plant and Equipment - Net	1,387,991			1,285,591
Investments:
Available-for-Sale Securities	8,237			7,520
Restricted Investments	2,077			1,268
Total Investments	10,314			8,788
Current Assets:
Cash and Cash Equivalents	1,694			2,678
Accounts Receivable	50,137			49,071
Accounts Receivable - Related Parties	1,316			961
Unbilled Revenues	7,464			35,351
Provision for Uncollectibles	(5,618		)	(3,985		)
Natural Gas in Storage, average cost	27,753			13,896
Materials and Supplies, average cost	1,682			1,560
Deferred Income Taxes - Net	9,759			—
Prepaid Taxes	14,108			17,046
Derivatives - Energy Related Assets	239			464
Other Prepayments and Current Assets	4,644			3,343
Total Current Assets	113,178			120,385
Regulatory and Other Noncurrent Assets:
Regulatory Assets	326,727			352,656
Unamortized Debt Issuance Costs	6,282			6,663
Long-Term Receivables	9,458			9,336
Derivatives - Energy Related Assets	67			302
Other	3,170			2,738
Total Regulatory and Other Noncurrent Assets	345,704			371,695
Total Assets	$	1,857,187		$	1,786,459

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

7

SOUTH JERSEY GAS COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

(In Thousands, except per share amounts)

	September 30, 2013			December 31, 2012
Capitalization and Liabilities
Common Equity:
Common Stock, Par Value $2.50 per share:
Authorized - 4,000,000 shares
Outstanding - 2,339,139 shares	$	5,848		$	5,848
Other Paid-In Capital and Premium on Common Stock	226,050			201,050
Accumulated Other Comprehensive Loss	(13,340		)	(13,285		)
Retained Earnings	368,065			327,782
Total Common Equity	586,623			521,395
Long-Term Debt	404,000			425,000
Total Capitalization	990,623			946,395
Current Liabilities:
Notes Payable	110,000			102,100
Current Portion of Long-Term Debt	21,000			25,000
Accounts Payable - Commodity	11,682			14,926
Accounts Payable - Other	31,279			25,498
Accounts Payable - Related Parties	5,506			5,872
Derivatives - Energy Related Liabilities	1,606			2,615
Deferred Income Taxes - Net	—			10,432
Customer Deposits and Credit Balances	20,482			17,450
Environmental Remediation Costs	25,662			19,203
Taxes Accrued	1,470			1,674
Pension Benefits	1,236			1,236
Interest Accrued	4,248			6,277
Other Current Liabilities	3,331			6,492
Total Current Liabilities	237,502			238,775
Regulatory and Other Noncurrent Liabilities:
Regulatory Liabilities	52,219			56,517
Deferred Income Taxes - Net	352,845			310,357
Environmental Remediation Costs	82,574			88,207
Asset Retirement Obligations	39,645			38,892
Pension and Other Postretirement Benefits	86,431			89,193
Investment Tax Credits	424			618
Derivatives - Energy Related Liabilities	179			80
Derivatives - Other	4,569			7,761
Other	10,176			9,664
Total Regulatory and Other Noncurrent Liabilities	629,062			601,289
Commitments and Contingencies (Note 9)
Total Capitalization and Liabilities	$	1,857,187		$	1,786,459

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

8

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

THE ENTITY - South Jersey Industries, Inc. (SJI) owns all of the outstanding common stock of South Jersey Gas Company (SJG), a regulated natural gas utility. SJG distributes natural gas in the seven southern most counties of New Jersey. In our opinion, the condensed financial statements reflect all normal and recurring adjustments needed to fairly present our financial position and operating results at the dates and for the periods presented. SJG’s business is 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, the accompanying condensed financial statements contain certain condensed financial information and exclude certain note disclosures normally included in annual audited financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These condensed financial statements should be read in conjunction with SJG’s 2012 Form 10-K for a more complete discussion of our accounting policies and certain other information.

REVENUE AND THROUGHPUT - BASED TAXES - SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both revenues and cost of sales, and totaled $0.5 million and $0.7 million for the three months ended September 30, 2013 and 2012, and $3.4 million and $4.0 million for the nine months ended September 30, 2013 and 2012, respectively. The TEFA is subject to a planned phase-out which decreased the assessment in increments of 25% in 2012 and 2013 and is eliminated after December 31, 2013.

NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2012 and 2013 had, or is expected to have, a material impact on the condensed financial statements.

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

In February 2013, in response to ASU 2011-12 discussed above, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.

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

9

2. STOCK-BASED COMPENSATION PLANS:

Officers and other key employees of SJG participate in the Stock Option, Stock Appreciation Rights and Restricted Stock Award Plan ("Plan") of SJI. Restricted shares issued under this plan vest over a three-year period and are subject to SJI achieving certain market or earnings-based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 150% of the original share units granted. Grants containing market-based

performance targets have been issued in each of the last three years and use SJI's total shareholder return (TSR) relative to a peer group to measure performance. Beginning with 2012, grants containing earnings-based targets have also been issued. These new grants are based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance.

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

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

Grant Date	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Jan. 2011 - TSR	7,116	$	50.94	27.5	%	1.01	%
Jan. 2012 - TSR	3,533	$	51.23	22.5	%	0.43	%
Jan. 2012 - EPS	3,533	$	56.93	n/a		n/a
Jan. 2013 - TSR	4,001	$	44.38	21.1	%	0.40	%
Jan. 2013 - EPS	4,001	$	51.18	n/a		n/a

Expected volatility is based on the actual volatility of SJI’s share price over the preceding three year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three year term of the restricted shares. As notional dividend equivalents are credited to the holders, which are reinvested during the three year service period, no reduction to the fair value of the award is required.

The cost for restricted stock awards during 2013 and 2012 is approximately $0.1 million per quarter.

As of September 30, 2013, there was $0.5 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 1.8 years.

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

	Shares		Weighted Average Grant Date Fair Value
Nonvested Shares Outstanding, January 1, 2013	15,108		$	52.55
Granted	9,324		$	47.78
Canceled / Forfeited	(2,248	)	$	50.02
Nonvested Shares Outstanding, September 30, 2013	22,184		$	50.80

10

During the nine months ended September 30, 2013, SJI awarded 12,901 shares that had vested at December 31, 2012, to SJG's officers and other key employees at a market value of $0.6 million. During the nine months ended September 30, 2012, SJI awarded 7,098 shares at a market value of $0.4 million to SJG's officers and other key employees. SJG has a policy of making cash payments to SJI to satisfy its obligations under this plan. Cash payments to SJI during each of the nine months ended September 30, 2013 and 2012 were approximately $0.4 million relating to stock awards. Additionally, a change in control could result in the nonvested shares becoming nonforfeitable or immediately payable in cash.

3. RATES AND REGULATORY ACTIONS:

SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). In January 2013, SJG credited the accounts of our periodic Basic Gas Supply Service (BGSS) customers with refunds totaling $9.4 million due to gas costs that were lower than projected.

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

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

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

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

In May 2013, SJG made its annual BGSS and CIP filing requesting a $17.9 million decrease in annual revenues. Provisional rates were approved by the BPU in September 2013 and effective October 1, 2013.

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

In October 2012, SJG filed a petition requesting a $13.2 million increase in annual revenues by rolling $110.6 million of CIRT I, II and III investments into base rates. In May 2013, SJG filed a supplemental petition requesting to roll an additional $6.9 million of CIRT III investments into base rates, for a total annual revenue increase of $15.5 million related to $117.5 million of CIRT investments made since our last base rate case in 2010. The BPU approved the petition in September 2013 with rates effective October 1, 2013.

In September 2013, SJG filed a petition requesting a Storm Hardening and Reliability Program (SHARP), pursuant to which SJG is proposing to invest approximately $280 million over seven years to replace low pressure distribution mains and services with high pressure distribution mains and services in coastal areas that are susceptible to flooding during major storm events. This petition is currently pending.

There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2012. See Note 3 to the Financial Statements in Item 8 of SJG's Form 10-K as of December 31, 2012.

11

4. REGULATORY ASSETS AND LIABILITIES:

There have been no significant changes to the nature of SJG’s regulatory assets and liabilities since December 31, 2012, which are described in Notes 3 and 4 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012.

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

	September 30, 2013		December 31, 2012
Environmental Remediation Costs:
Expended - Net	$	30,189	$	37,892
Liability for Future Expenditures	108,236		107,410
Deferred Asset Retirement Obligation Costs	30,607		30,199
Deferred Pension and Other Postretirement Benefit Costs	95,897		95,897
Conservation Incentive Program Receivable	12,573		31,686
Societal Benefit Costs Receivable	12,816		12,801
Premium for Early Retirement of Debt	976		1,075
Deferred Interest Rate Contracts (Note 11)	4,569		7,761
Energy Efficiency Tracker	12,263		12,306
Pipeline Supplier Service Charges	7,522		8,771
Other Regulatory Assets	11,079		6,858
Total Regulatory Assets	$	326,727	$	352,656

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

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

	September 30, 2013		December 31, 2012
Excess Plant Removal Costs	$	41,128	$	45,593
Deferred Revenues-Net	8,352		10,924
Other Regulatory Liabilities	2,739		—
Total Regulatory Liabilities	$	52,219	$	56,517

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

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5. RELATED PARTY TRANSACTIONS:

There have been no significant changes in the nature of SJG’s related party transactions since December 31, 2012. See Note 5 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012 for a detailed description of such transactions.

A summary of related party transactions, excluding pass-through items, included in Operating Revenues were as follows, (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013		2012
Operating Revenues/Affiliates:
SJRG	$	344	$	211	$	1,194	$	483
Other	335		312		974		499
Total Operating Revenue/Affiliates	$	679	$	523	$	2,168	$	982

Related party transactions, excluding pass-through items, included in Operating Expenses were as follows, (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013		2012
Costs of Sales/Affiliates (Excluding depreciation):
SJRG	$	5,436	$	2,683	$	11,105	$	8,445
Energy-Related Derivative (Gains) / Losses *
SJRG	$	389	$	3,011	$	568	$	13,666

* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.

Operations Expense/Affiliates
SJI	$	2,737		$	2,237		$	8,613		$	7,400
SJIS	1,330			1,240			4,264			3,833
Millennium	665			796			2,014			2,379
Other	(103		)	(99		)	(336		)	(377		)
Total Operations Expense/Affiliates	$	4,629		$	4,174		$	14,555		$	13,235

6. FINANCIAL INSTRUMENTS:

RESTRICTED INVESTMENTS - In accordance with the terms of our tax-exempt first mortgage bonds, unused proceeds are required to be escrowed pending approved construction expenditures. As of both September 30, 2013 and December 31, 2012, the escrowed proceeds, including interest earned, totaled $0.1 million. SJG established a margin account with SJRG in conjunction with SJG's risk management activities as detailed in Note 11. The funds provided by SJG will increase or decrease as the number and value of outstanding energy-related contracts held with SJRG changes. As of September 30, 2013 and December 31, 2012, the balance held with SJRG totaled $0.9 million and $1.1 million, respectively. During March 2013, SJG established a margin account with a counterparty in conjunction with SJG's risk management activities as detailed in Note 11. The funds provided by SJG will increase or decrease as the number and value of outstanding energy-related contracts held with this counterparty changes. As of September 30, 2013 the balance held with this counterparty totaled $1.0 million. The carrying amounts of the Restricted Investments approximate their fair value at September 30, 2013 and December 31, 2012, which would be included in Level 1 of the fair value hierarchy. (See Note 10 - Fair Value of Financial Assets and Financial Liabilities).

13

LONG-TERM RECEIVABLES– SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources.  The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest.  The carrying amounts of such loans were $14.0 million and $13.6 million as of September 30, 2013 and December 31, 2012, respectively.  The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Long-Term Receivables on the condensed balance sheets.  The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.3 million as of both September 30, 2013 and December 31, 2012.  The annual amortization to interest is not material to SJG’s financial statements.  The carrying amounts of these receivables approximate their fair value at September 30, 2013 and December 31, 2012, which would be included in Level 2 of the fair value hierarchy. (See Note 10 - Fair Value of Financial Assets and Financial Liabilities).

FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJG's financial instruments approximate their fair values at September 30, 2013 and December 31, 2012, except as noted below.

• For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to SJG at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy. See Note 10 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJG's long-term debt, including current maturities, as of September 30, 2013 and December 31, 2012, were $446.2 million and $502.0 million, respectively.  The carrying amount of SJG's long-term debt, including current maturities, as of September 30, 2013 and December 31, 2012 was $425.0 million and $450.0 million respectively.

7. UNUSED LINES OF CREDIT:

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

	Total Facility		Usage		Available Liquidity		Expiration Date
Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	110,000	$	90,000	May 2018
Uncommitted Bank Lines	10,000		—		10,000		August 2014
Total	$	210,000	$	110,000	$	100,000

The SJG facility is provided by a syndicate of banks and contains one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the credit agreement) to not more than 0.65 to 1 measured at the end of each fiscal quarter.  SJG was in compliance with this covenant as of September 30, 2013.

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

Average borrowings outstanding under these credit facilities during the nine months ended September 30, 2013 and 2012 were $90.5 million and $146.3 million, respectively.  The maximum amount outstanding under these credit facilities during the nine months ended September 30, 2013 and 2012 were $119.9 million and $180.5 million, respectively.

Based upon the existing credit facilities and a regular dialogue with our banks, we believe that there will continue to be sufficient credit available to meet our business’ future liquidity needs. Borrowings under these credit facilities are at market rates.  The weighted average interest rate on these borrowings, which changes daily, was 0.34% and 0.47% at September 30, 2013 and 2012, respectively.

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8. PENSION AND OTHER POSTRETIREMENT BENEFITS:

For the three and nine months ended  September 30, 2013 and 2012, net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):

	Pension Benefits						Pension Benefits
	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
Service Cost	$	1,040		$	873		$	3,120		$	2,619
Interest Cost	1,811			1,853			5,434			5,559
Expected Return on Plan Assets	(2,286		)	(1,991		)	(6,859		)	(5,974		)
Amortizations:
Prior Service Cost	48			48			144			145
Actuarial Loss	1,729			1,469			5,185			4,407
Net Periodic Benefit Cost	2,342			2,252			7,024			6,756
Capitalized Benefit Costs	(1,218		)	(1,306		)	(3,653		)	(3,513		)
Total Net Periodic Benefit Expense	$	1,124		$	946		$	3,371		$	3,243

	Other Postretirement Benefits						Other Postretirement Benefits
	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
Service Cost	$	212		$	198		$	637		$	594
Interest Cost	509			573			1,526			1,719
Expected Return on Plan Assets	(443		)	(402		)	(1,329		)	(1,206		)
Amortizations:
Prior Service Credits	(53		)	(54		)	(159		)	(162		)
Actuarial Loss	324			329			972			988
Net Periodic Benefit Cost	549			644			1,647			1,933
Capitalized Benefit Costs	(285		)	(374		)	(856		)	(1,005		)
Total Net Periodic Benefit Expense	$	264		$	270		$	791		$	928

Capitalized benefit costs reflected in the table above relate to our construction program.

SJG contributed $9.1 million and $19.8 million to the pension plans in January 2013 and 2012, respectively. No additional contributions are expected to be made to the pension plans during 2013. Payments related to the unfunded Supplemental Executive Retirement Plan (SERP) are expected to approximate $1.2 million in 2013. We also have a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred.

See Note 11 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012 for additional information related to SJG’s pension and other postretirement benefits.

9. COMMITMENTS AND CONTINGENCIES:

STANDBY LETTER OF CREDIT -    SJG provided a $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 New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system. 

ENVIRONMENTAL REMEDIATION COSTS - SJG 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. There have been no significant changes to the status of SJG’s environmental remediation efforts since December 31, 2012, as described in Note 12 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012.

15

GAS SUPPLY RELATED CONTRACTS - In the normal course of conducting business, we have entered into long-term contracts for natural gas supplies, firm transportation and gas storage service. The earliest date at which any of the primary terms of these contracts expire is October 2014. The transportation and storage agreements entered into between us and each of our interstate pipeline service providers were done so in accordance with their respective FERC approved tariff. Our cumulative obligation for gas supply related demand charges and reservation fees paid for these services averages approximately $4.3 million per month and is recovered on a current basis through the BGSS.

PENDING LITIGATION - We are subject to claims arising in the ordinary course of business and other legal proceedings. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $0.4 million and $0.5 million related to all claims in the aggregate, as of September 30, 2013 and December 31, 2012, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.

COLLECTIVE BARGAINING AGREEMENTS - Unionized personnel represent approximately 60% of our workforce at September 30, 2013. The Company has collective bargaining agreements with two unions who represent these employees: the International Brotherhood of Electrical Workers (IBEW) operates under a collective bargaining agreement that runs through February 28, 2017, and the International Association of Machinists and Aerospace Workers (IAM) operates under a collective bargaining agreement that expires in August 2014.

10. FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES:

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

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

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

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

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

For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands):

As of September 30, 2013
	Total		Level 1		Level 2		Level 3
Assets -
Available-for-Sale Securities (A)	$	8,237	$	8,237	$	—	$	—
Derivatives – Energy Related Assets (B)	306		306		—		—
	$	8,543	$	8,543	$	—	$	—
Liabilities -
Derivatives – Energy Related Liabilities (B)	$	1,785	$	1,466	$	—	$	319
Derivatives – Other (C)	4,569		—		4,569		—
	$	6,354	$	1,466	$	4,569	$	319

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As of December 31, 2012
	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,520	$	769	$	6,751	$	—
Derivatives - Energy Related Assets (B)	766		447		319		—
	$	8,286	$	1,216	$	7,070	$	—
Liabilities
Derivatives - Energy Related Liabilities (B)	$	2,695	$	2,694	$	1	$	—
Derivatives - Other (C)	7,761		—		7,761		—
	$	10,456	$	2,694	$	7,762	$	—

(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 consisted of funds that are not publicly traded.  These funds, which consisted 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. 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. 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. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.

Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

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

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

Type	Fair Value at September 30, 2013		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$—	$319	Discounted Cash Flow	Forward price (per dt)	$(1.75) - $(1.75) [$(1.75)]

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

	Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
Balance at beginning of period	$	(243	)	$	—
Total losses unrealized in Regulatory Liabilities (see note 4)	(76		)	(319		)
Settlements	—			—
	(76		)	(319		)
Balance at September 30	$	(319	)	$	(319	)

11. DERIVATIVE INSTRUMENTS:

SJG is involved in buying, selling, transporting and storing natural gas and is subject to market risk on expected future purchases and sales due to commodity price fluctuations. The Company, through its affiliate South Jersey Resources Group (SJRG) and another counterparty, 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, futures contracts, swap agreements and options contracts. As of September 30, 2013, SJG had outstanding derivative contracts intended to limit the exposure to market risk on 6.5 MMdts of expected future purchases of natural gas. These contracts, which do not qualify for the normal purchase and sale exemption and 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 balance sheets. The costs or benefits of these short-term contracts are recoverable through SJG’s Basic Gas Supply Service (BGSS) clause, subject to BPU approval. As a result, the net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the condensed balance sheets. As of September 30, 2013 and December 31, 2012, SJG had $1.5 million and $1.9 million of unrealized losses, respectively, included in its BGSS related to open financial contracts.

The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives-Other on the condensed balance sheets. The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates. There have been no significant changes to the Company’s active interest rate swaps since December 31, 2012 which are described in Note 1 to the Financial Statements in Item 8 of SJG’s Annual Report on Form 10-K as of December 31, 2012. Subject to BPU approval, the market value upon termination of these interest rate derivatives can be recovered in rates and, therefore, these unrealized losses have been included in Regulatory Assets on the condensed balance sheets.

We previously used derivative transactions known as “Treasury Locks” to hedge against the impact on our cash flows of possible interest rate increases on debt issued in September 2005.  The initial $1.4 million cost of the Treasury Locks has been included in Accumulated Other Comprehensive Loss and is being amortized over the 30 year life of the associated debt issue.  As of September 30, 2013 and December 31, 2012, the unamortized balance was approximately $1.0 million and $1.1 million, respectively.

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

Derivatives not designated as hedging instruments under GAAP	September 30, 2013				December 31, 2012
	Assets		Liabilities		Assets		Liabilities
Energy related commodity contracts:
Derivatives – Energy Related – Current	$	239	$	1,606	$	464	$	2,615
Derivatives – Energy Related – Non-Current	67		179		302		80
Interest rate contracts:
Derivatives – Other	—		4,569		—		7,761
Total derivatives not designated as hedging instruments under GAAP	306		6,354		766		10,456
Total Derivatives	$	306	$	6,354	$	766	$	10,456

For derivative instruments disclosed in the table above, information as to the presentation on the condensed balance sheets is as follows (in thousands):

As of September 30, 2013
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	306		$	—	$	306		$	(306	)	(A)	$	—	$	—
Derivatives - Energy Related Liabilities	(1,785		)	—		(1,785		)	306			(B)	1,160		(319		)
Derivatives - Other	(4,569		)	—		(4,569		)	—				—		(4,569		)

As of December 31, 2012
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	766		$	—	$	766		$	(447	)	(A)	$	—	$	319
Derivatives - Energy Related Liabilities	(2,695		)	—		(2,695		)	447			(B)	1,136		(1,112		)
Derivatives - Other	(7,761		)	—		(7,761		)	—				—		(7,761		)

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

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

The effect of derivative instruments on the condensed statements of income for the three and nine months ended September 30, 2013 and 2012 are as follows (in thousands):

	Three months ended September 30,						Nine months ended September 30,
Derivatives in Cash Flow Hedging Relationships	2013			2012			2013			2012
Interest Rate Contracts:
Losses reclassified from accumulated OCL into income (a)	$	(12	)	$	(12	)	$	(36	)	$	(36	)

(a) Included in Interest Charges

Net realized losses of $0.4 million and $3.0 million associated with SJG's energy related financial commodity contracts for the three months ended September 30, 2013 and 2012 and losses of $0.6 million and $13.7 million for the nine months ended September 30, 2013 and 2012, 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.

12. LONG-TERM DEBT:

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

During the third quarter of 2013, SJG redeemed at par $10.5 million of 4.46% MTN's issued in July 2003 and $14.5 million of 5.027% MTN's issued in September 2003.

In September 2013, SJG agreed in principle to issue $80.0 million of MTN's under a private placement. SJG expects to issue $50.0 million of 4.01% MTN's in November 2013, due November 2030, and $30.0 million of 4.23% MTN's in January 2014, due January 2030.

We retire debt when it is cost effective as permitted by the debt agreements.  Our long-term debt agreements contain no financial covenants.

The Company did not issue any long-term debt during the nine months ended September 30, 2013.

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13.    ACCUMULATED OTHER COMPREHENSIVE LOSS:

The changes in Accumulated Other Comprehensive Loss (AOCL) for the three and nine months ended September 30, 2013 are as follows (in thousands):

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Total
Balance at July 1, 2013 (a)	$	(12,958	)	$	(607	)	$	(3	)	$	(13,568	)
Other comprehensive income before reclassifications	—			—			221			221
Amounts reclassified from AOCL (b)	—			7			—			7
Net current period other comprehensive income (loss)	—			7			221			228
Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Total
Balance at January 1, 2013 (a)	$	(12,958	)	$	(621	)	$	294		$	(13,285	)
Other comprehensive income before reclassifications	—			—			413			413
Amounts reclassified from AOCL (b)	—			21			(489		)	(468		)
Net current period other comprehensive income (loss)	—			21			(76		)	(55		)
Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)

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

(b) See table below.

The reclassifications out of AOCL and into earnings during the three and nine months ended September 30, 2013 is as follows (in thousands):

Components of AOCL	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Statements of Income
	Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		$	36		Interest Charges
Unrealized Gain on Available-for-Sale Securities	—			(828		)	Other Income & Expense
	12			(792		)	Loss (Income) Before Income Taxes
Income Taxes (a)	(5		)	324			Income Taxes (a)
Losses (Gains) from reclassifications for the period net of tax	$	7		$	(468	)

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

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14.     EQUITY CONTRIBUTION:

We received an equity infusion of $25.0 million from SJI during September 2013. Contributions of capital are credited to Other Paid-In Capital and Premium on Common Stock. Further equity contributions will occur on an as needed basis.

15.    SUBSEQUENT EVENT:

In October 2013, SJG filed a petition with the New Jersey Board of Public Utilities to issue up to $200.0 million of long term debt securities in various forms including Medium Term Notes and unsecured debt, with maturities of more than 12 months, over the next three years. This petition is currently pending.

Item 2. Management’s Discussion and Analysis

of Financial Condition and Results of Operations

OVERVIEW:

Organization - We are an operating public utility company engaged in the purchase, transmission and sale of natural gas for residential, commercial and industrial use. We also sell natural gas and pipeline transportation capacity (off-system sales) on a wholesale basis to various customers on the interstate pipeline system and transport natural gas purchased directly from producers or suppliers to their customers. We served 359,273 customers at September 30, 2013 compared with 354,468 customers at September 30, 2012.

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 by the Company 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 or suppliers to fulfill their contractual obligations; and changes in business strategies.

A discussion of these and other risks and uncertainties may be found in SJG’s Form 10-K for the year ended December 31, 2012 and in other filings made by us with the Securities and Exchange Commission. 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 SJG 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, SJG 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 financial statements and related disclosures. Actual results could differ from those estimates. Five types of transactions presented in our condensed financial statements require a significant amount of judgment and estimation.

These relate to regulatory accounting, derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition. A discussion of these estimates and assumptions may be found in SJG’s Form 10-K for the year ended December 31, 2012.

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

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Regulatory Actions – SJG has made the appropriate notice to the New Jersey Board of Public Utilities of our intent to file a rate case by the end of November 2013. Other than the changes discussed in Note 3 to the condensed financial statements, there have been no significant regulatory actions since December 31, 2012. See detailed discussions concerning Regulatory Actions in Note 3 to the Financial Statements in item 8 of SJG’s Form 10-K for the year ended December 31, 2012.

Environmental Remediation –There have been no significant changes to the status of SJG’s environmental remediation efforts since December 31, 2012. See detailed discussion concerning Environmental Remediation in Note 12 to the Financial Statements in Item 8 of SJG’s Form 10-K for the year ended December 31, 2012.

Competition- See detailed discussion concerning competition in SJG’s Form 10-K for the year ended December 31, 2012.

Customer Choice Legislation- All residential natural gas customers in New Jersey can choose their natural gas commodity supplier under the terms of the “Electric Discount and Energy Competition Act of 1999.” This bill created the framework and necessary time schedules for the restructuring of the state’s electric and natural gas utilities. The Act established unbundling, under which redesigned utility rate structures allow natural gas and electric consumers to choose their energy supplier. Customers purchasing natural gas from a provider other than the local utility (marketer) are charged for the gas costs by the marketer and charged for the transportation costs by the utility. The number of customers purchasing their natural gas from marketers was 47,494 and 41,857 at September 30, 2013 and 2012, respectively.

RESULTS OF OPERATIONS:

The following table summarizes the composition of selected gas utility data for the three and nine months ended September 30, (in thousands, except for degree day data):

	Three Months Ended September 30,		Nine Months Ended September 30,
	2013	2012	2013	2012
Utility Throughput – dt:
Firm Sales -
Residential	1,290	1,327	15,165	12,216
Commercial	507	585	3,694	3,202
Industrial	21	18	204	180
Cogeneration & Electric Generation	781	834	1,346	1,328
Firm Transportation -
Residential	200	171	2,275	1,411
Commercial	621	552	4,685	3,717
Industrial	2,983	3,051	9,711	9,545
Cogeneration & Electric Generation	2,392	3,400	6,166	7,465
Total Firm Throughput	8,795	9,938	43,246	39,064
Interruptible Sales	—	—	14	2
Interruptible Transportation	275	264	1,014	1,005
Off-System	2,931	1,176	6,098	6,727
Capacity Release	8,554	16,488	29,515	50,474
Total Throughput - Utility	20,555	27,866	79,887	97,272

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	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013		2012
Utility Operating Revenues:
Firm Sales -
Residential	$	22,477	$	25,618	$	164,399	$	172,271
Commercial	7,404		7,571		38,806		36,862
Industrial	312		327		2,469		1,961
Cogeneration & Electric Generation	3,759		3,298		6,922		5,226
Firm Transportation -
Residential	2,343		1,864		14,707		9,945
Commercial	3,401		2,802		18,763		15,851
Industrial	5,765		5,239		17,083		15,847
Cogeneration & Electric Generation	1,581		2,170		5,186		5,412
Total Firm Revenues	47,042		48,889		268,335		263,375
Interruptible Sales	—		—		339		50
Interruptible Transportation	360		278		1,275		1,094
Off-System	10,728		4,051		23,983		22,934
Capacity Release	1,291		786		5,665		4,632
Other	253		247		711		779
Total Utility Operating Revenues	59,674		54,251		300,308		292,864
Less:
Cost of Sales (Excluding depreciation)	24,717		21,053		128,427		127,959
Conservation Recoveries*	2,374		1,259		10,446		6,101
RAC Recoveries*	2,178		1,912		6,533		5,735
EET Recoveries*	1,245		797		3,436		2,352
Revenue and Throughput Taxes	478		650		3,417		4,025
Utility Margin	$	28,682	$	28,580	$	148,049	$	146,692
Margin:
Residential	$	14,513	$	14,484	$	95,649	$	80,100
Commercial and Industrial	8,143		8,385		39,067		35,865
Cogeneration and Electric Generation	1,390		1,620		3,828		3,749
Interruptible	11		12		91		64
Off-system & Capacity Release	352		213		1,269		1,309
Other Revenues	518		409		1,283		1,181
Margin Before Weather Normalization & Decoupling	24,927		25,123		141,187		122,268
CIRT Mechanism	728		756		2,204		2,286
CIP Mechanism	2,901		2,586		4,278		21,819
EET Mechanism	126		115		380		319
Utility Margin	$	28,682	$	28,580	$	148,049	$	146,692
Degree Days:	68		26		3,020		2,323

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

24

Throughput– Total gas throughput decreased 7.3 MMdts, or 26.2%, for the three months ended September 30, 2013, compared with the same period in 2012.  This decrease was realized primarily in Capacity Release activity which decreased 7.9 MMdts during the three months ended September 30, 2013, as compared with the same period in 2012. In 2013, SJG entered into a new asset management agreement (AMA) with a third party that allocated a significant amount of capacity for a fixed fee. Volumes released under AMA's are not included in the throughput table above. This transfer of capacity rights left less available for SJG's normal release activity. In addition, SJG was releasing capacity in smaller segments ("segmenting") in 2012 based on the demand in the market at that time. While segmenting has little impact on total revenue generated from such activity, it does increase the throughput significantly. Firm throughput decreased 1.1 MMdts, or 11.5%, during the three months ended September 30, 2013, compared to the same period in 2012.  This primarily occurred in the electric generation market where throughput decreased 1.1 MMdts, or 25.1%. The third quarter of 2012 was one of the warmest on record in the region, which drove the demand for greater natural gas consumption by the region's electric producers. These decreases were partially offset by higher Off-System Sales (OSS) which increased by 1.8 MMdts as more profitable market opportunities presented themselves in the third quarter versus the same period last year.

Total gas throughput decreased 17.4 MMdts, or 17.9%, for the nine months ended September 30, 2013, compared with the same period in 2012. This decrease was realized primarily in the Capacity Release market which decreased 21.0 MMdts during the nine months ended September 30, 2013, as compared with the same period in 2012. Contributing to the decrease in Capacity Release throughput was the new AMA and less segmenting of capacity release in 2013, discussed above as part of the three month results. Due to colder weather experienced in the region during the first quarter of 2013, SJG also experienced an increased demand by its firm customers, thereby creating fewer opportunities for Capacity Release during the winter months. Firm throughput increased 4.2 MMdts, or 10.7%, during the nine months ended September 30, 2013, compared to the same period in 2012. This is most apparent in the heat sensitive residential and commercial markets whose throughput increased as a result of weather that was 29.7% colder for the nine months ended September 30, 2013, as compared with the same period last year. Also contributing to higher firm throughput was the addition of 4,805 customers over the last twelve months, representing 1.4% customer growth.

Operating Revenues – Revenues increased $5.4 million, or 10.0%, during the three months ended September 30, 2013, compared with the same period in the prior year. Higher OSS volume, coupled with higher per unit sales prices, resulted in a $6.7 million increase in OSS revenues during the three months ended September 30, 2013, compared with the same period last year. As reflected in the Margin table above, the impact of changes in OSS and capacity release activity do not have a material impact on the earnings of SJG, as SJG is required to share 85% of the profits of such activity with our ratepayers. Total firm revenue decreased $1.8 million, or 3.8%, during the third quarter of 2013 versus the same period in 2012. As stated under "Throughput," weather that was not as warm as last year led to decreased firm sales volume from the electric generation market and lower firm revenue. Lower gas costs being passed through to residential and small commercial customers also led to lower firm revenue, as SJG reduced its BGSS rate by 18% in October 2012. While changes in gas costs and BGSS recoveries/refunds may fluctuate from period to period, SJG does not profit from the sale of the commodity.  Therefore, corresponding fluctuations in Operating Revenue or Cost of Sales have no impact on Company profitability, as further discussed below under the caption “Margin.”

Revenues increased $7.4 million, or 2.5%, during the nine months ended September 30, 2013, compared with the same period in the prior year. Total firm revenue increased $5.0 million, or 1.9%, during the nine months ended September 30, 2013 versus the same period in 2012. As stated under "Throughput," colder weather increased firm sales volume significantly compared with prior year; however, associated firm revenue did not increase proportionately. This is the result of lower gas costs being passed through to those customers, as SJG reduced its BGSS rate by 18% in October 2012. In addition, SJG gave a refund of $9.4 million to its periodic BGSS customers in January 2013, which further reduced revenue. As previously stated, SJG does not profit from the sale of the commodity. Therefore, corresponding fluctuations in Operating Revenue or Cost of Sales have no impact on Company profitability, as further discussed below under the caption "Margin." Higher OSS and capacity release unit prices resulted in a $2.1 million increase in revenues during the nine months ended September 30, 2013, compared with the same period last year. As previously stated, the impact of changes in OSS and capacity release activity do not have a material impact on the earnings of SJG, as SJG is required to share 85% of the profits of such activity with our ratepayers.

25

Conservation Incentive Program (CIP) - The effects of the CIP on our net income and the associated weather comparisons were as follows ($’s in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013			2012
Net Income Benefit:
CIP – Weather Related	$	—	$	—	$	(0.7	)	$	7.6
CIP – Usage Related	1.7		1.5		3.2			5.3
Total Net Income Benefit	$	1.7	$	1.5	$	2.5		$	12.9
Weather Compared to 20-Year Average	n/a		n/a		1.8% colder			23.4% warmer
Weather Compared to Prior Year	n/a		n/a		29.7% colder			19.7% warmer

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

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

Total margin increased $1.4 million, or 0.9%, for the nine months ended September 30, 2013, compared with the same period in 2012, primarily due to customer additions.  SJG added 4,805 customers over the 12-month period ended September 30, 2013, representing growth of 1.4% over the prior year and a corresponding increase in margin.

As reflected in the margin table and the CIP table above, the CIP protected $4.3 million, or $2.5 million after taxes, in the first nine months of 2013 that would have been lost due to lower customer usage, compared with $21.8 million, or $12.9 million after taxes, during the same period last year.

Operating Expenses - A summary of changes in operating expenses (in thousands):

	Three Months Ended September 30, 2013 vs. 2012			Nine Months Ended September 30, 2013 vs. 2012
Operations	$	1,077		$	5,455
Maintenance	$	(217	)	$	7
Depreciation	$	679		$	2,118
Energy and Other Taxes	$	(115	)	$	(483	)

Operations – Operations expense increased $1.1 million and $5.5 million for the three and nine month periods ended September 30, 2013, as compared with the same periods in 2012, respectively.  The increase is primarily due to the spending under the New Jersey Clean Energy Program and Energy Efficiency Programs which increased $1.6 million and $5.4 million for the three and nine month periods ended September 30, 2013, as compared to 2012, respectively. Such costs are recovered on a dollar-for-dollar basis; therefore, SJG experienced an offsetting increase in revenues during the period.

Maintenance - Changes in maintenance expense for the three and nine month periods ended September 30, 2013, compared with the same periods in 2012, were not significant.

Depreciation - Depreciation expense increased $0.7 million and $2.1 million during the three and nine month periods ended September 30, 2013, compared with the same periods in 2012, respectively, due mainly to our continuing investment in property, plant & equipment.

26

Energy and Other Taxes - Energy and Other Taxes decreased $0.1 million and $0.5 million during the three and nine month periods ended September 30, 2013, compared with the same periods in 2012, respectively. This was primarily due to a 25% decrease in the Company's primary energy tax, the Transitional Energy Facilities Assessment, effective January 1, 2013, partially offset by higher year-to-date taxable firm throughput in 2013 resulting from significantly colder weather during 2013.  Additional weather information can be found above under the caption “Conservation Incentive Program (CIP).”

Other Income and Expense - Other Income and Expense decreased $0.9 million and $1.5 million for the three and nine month periods ended September 30, 2013, compared with the same periods in 2012. With the approval of the Company's Accelerated Infrastructure Replacement Program (AIRP) in February 2013, equity-related returns on all ongoing accelerated capital programs were reduced. However, there was a corresponding BPU-approved increase in the Company's capitalization of interest costs, as noted below.

Interest Charges–  Interest Charges decreased $1.2 million and $3.5 million during the three and nine month periods ended September 30, 2013, compared with the same periods in 2012, respectively, due to higher capitalization of interest costs on construction during 2013 as a result of the approval of the Company's AIRP program in February 2013, as discussed above. Also contributing to the decrease is the impact of retiring $35.0 million of higher priced long-term debt during 2012. The decrease is partially offset by the issuance of $85.0 million of Medium Term Notes during the second half of 2012.

Income Taxes– Income tax expense generally fluctuates as income before income taxes changes. Minor variations will occur period to period as a result of effective tax rate adjustments.

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 Basic Gas Supply Service charge; the timing of construction and remediation expenditures and related permanent financings; 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 $110.0 million and $51.0 million in the first nine months of 2013 and 2012, respectively.  Net cash provided by operating activities varies from year-to-year primarily due to the impact of weather on customer demand and related gas purchases, customer usage factors related to conversion efforts and the price of the natural gas commodity, inventory utilization, and gas cost recoveries.  Net cash provided by operations was positively impacted by higher collections under regulatory clauses during the first nine months of 2013 that were under-recovered as a result of warmer-than-normal weather in 2012. Lower pension contributions also improved cash flows for the first nine months of 2013 as discussed on Note 8 to the condensed financial statements.  The Company strives to keep its pension plans fully funded.  When factors such as lesser than expected asset performance and/or declining discount rates negatively impact the funding status of the plans, the Company increases its contributions to supplant that funding shortfall.  While discount rates continued to decline, greater than expected asset performance during 2012 added significantly to improving the Company's funding status, which resulted in a decrease in the pension contribution during 2013.The Company contributed $9.1 million and $19.8 million to its pension plan in January 2013 and 2012, respectively.

Cash Flows from Investing Activities - SJG has a continuing need for cash resources for capital purchases, primarily to invest in new and replacement facilities and equipment. Cash used for capital purchases was $118.4 million and $114.9 million during the first nine months of 2013 and 2012, respectively.   We estimate the net cash outflows for construction projects for fiscal years 2013, 2014 and 2015 to be approximately $183.3 million$248.7 million and $185.0 million, respectively.  For capital expenditures, including those under the CIRT and AIRP, SJG expects to use short-term borrowings to finance capital expenditures as incurred.  From time to time, the Company may refinance the short-term debt incurred to support capital expenditures with long-term debt.

Cash Flows from Financing Activities - SJG uses short-term borrowings under lines of credit from commercial banks, or under its commercial paper program discussed below, to supplement cash from operations, to support working capital needs and to finance capital expenditures as incurred. From time to time, the Company refinances short-term debt incurred to finance capital expenditures with long-term debt. Debt is incurred primarily to expand and upgrade our gas transmission and distribution system and to support seasonal working capital needs related to inventories and customer receivables. In September 2013, SJG received an equity infusion of $25.0 million from SJI.

27

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

	Total Facility		Usage		Available  Liquidity		Expiration Date
Commercial Paper/Revolving Credit Facilities	$	200,000	$	110,000	$	90,000	May 2018
Uncommitted Bank Lines	10,000		—		10,000		August 2014
Total	$	210,000	$	110,000	$	100,000

SJG renewed the uncommitted bank lines of credit during the third quarter 2013. SJG amended and extended its revolving credit facility during the third quarter; as a result, the maturity date was extended from May 2015 to May 2018.

The SJG facility is provided by a syndicate of banks and contains one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the credit agreement) to not more than 0.65 to 1, measured at the end of each fiscal quarter.  SJG was in compliance with this covenant as of September 30, 2013.

SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million.  The notes 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 $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.

Average borrowings outstanding under the commercial paper program/revolving credit facility during the nine months ended September 30, 2013 and 2012 were $90.5 million and $146.3 million, respectively.  The maximum amount outstanding under these credit facilities during the nine months ended September 30, 2013 and 2012 were $119.9 million and $180.5 million, respectively.

Based upon the existing credit facilities and a regular dialogue with our banks, we believe there will continue to be sufficient credit available to meet our future liquidity needs.

SJG 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 our long-term borrowing needs. These needs are primarily capital expenditures for property, plant and equipment.

During the third quarter of 2013, SJG redeemed at par $10.5 million of 4.46% MTN's issued in July 2003 and $14.5 million of 5.027% MTN's issued in September 2003.

In September 2013, SJG agreed in principle to issue $80.0 million of MTN's under a private placement. SJG expects to issue $50.0 million of 4.01% MTN's in November 2013, due November 2030, and $30.0 million of 4.23% MTN's in January 2014, due January 2030.

In October 2013, SJG filed a petition with the New Jersey Board of Public Utilities to issue up to $200.0 million of long term debt securities in various forms including Medium Term Notes and unsecured debt, with maturities of more than 12 months, over the next three years. This petition is currently pending.

SJG’s capital structure was as follows:

	As of September 30,  2013		As of December 31, 2012
Common Equity	52	%	49	%
Long-Term Debt	38		42
Short-Term Debt	10		9
Total	100	%	100	%

28

COMMITMENTS AND CONTINGENCIES:

SJG has a continuing need for cash resources and capital, primarily to invest in new and replacement facilities and equipment, working capital, and for environmental remediation costs. Cash outflows for capital expenditures for the first nine months of 2013 and 2012 amounted to $118.4 million and $114.9 million, respectively. Management estimates net cash outflows for construction projects for 2013, 2014 and 2015, to be approximately $183.3 million$248.7 million and $185.0 million respectively.  Costs for remediation projects, net of insurance reimbursements, for the first nine months of 2013 and 2012 amounted to net cash inflows of $1.0 million and $0.9 million, respectively.  Total cash outflows for remediation projects are expected to be $10.8 million, $24.5 million and $24.2 million for 2013, 2014, and 2015, respectively.  As discussed in Notes 4 and 12 to the Financial Statements in Item 8 of SJG’s 10-K as of December 31, 2012, environmental remediation costs are subject to recovery from ratepayers.

SJG provided a $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.  

SJG has certain commitments for interstate pipeline capacity, storage services, Liquefied Natural Gas (LNG) and LNG transportation services, which carry demand type charges for which it pays fees regardless of usage. Those commitments as of September 30, 2013, average $51.5 million annually and total $233.7 million over the contracts’ lives.  Approximately 39% of the financial commitments under these contracts expire during the next five years. SJG expects to renew each of these contracts under renewal provisions as provided in each contract. SJG recovers all prudently incurred fees through rates via the BGSS.

Contractual Cash Obligations –   Details concerning contractual cash obligations may be found in SJG’s Form 10-K for the year ended December 31, 2012.  There were no significant changes to SJG's contractual cash obligations from December 31, 2012 except for long term debt, which decreased by $25.0 million due to scheduled redemptions during the third quarter of 2013.

Off-Balance Sheet Arrangements- We have no off-balance sheet arrangements.

Pending Litigation - We are 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. The Company has accrued approximately $0.4 million and $0.5 million related to all claims in the aggregate, as of September 30, 2013 and December 31, 2012, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.

Ratio of Earnings to Fixed Charges- Our ratio of earnings to fixed charges for each of the periods indicated is as follows:

Twelve Months Ended September 30,	Year Ended December 31,
2013	2012	2011	2010	2009	2008
5.0x	5.5x	5.3x	5.1x	4.9x	4.4x

The ratio of earnings to fixed charges represents, on a pre-tax basis, the number of times earnings covers fixed charges. Earnings consist of net income, to which has been added fixed charges and taxes. Fixed charges consist of interest charges (rentals are not material).

Item 3. Quantitative and Qualitative Disclosures about Market Risks

MARKET RISKS:

Commodity Market Risks - We are involved in buying, selling, transporting and storing natural gas and 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, futures and options agreements. To manage these transactions, we have 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.

29

We transact commodities on a physical and financial basis. South Jersey Resources Group, LLC (SJRG), an affiliate by common ownership, manages some of our risk by entering into the types of transactions noted above. As part of our gas purchasing strategy, we use financial contracts through SJRG and another counterparty to hedge against forward price risk. These contracts are recoverable through our BGSS, subject to BPU approval. The majority of our contracts are typically less than 12-months long. The fair value and maturity of these energy trading and hedging contracts determined using mark-to-market accounting as of September 30, 2013 is as follows (in thousands):

Assets
Source of Fair Value	Maturity < 1 Year		Maturity 1 - 3 Years		Total
Prices Actively Quoted (NYMEX)	$	239	$	67	$	306
Prices Provided by Other External Sources (Basis)	—		—		—
Prices based on internal models or other valuable methods	—		—		—
Total	$	239	$	67	$	306

Liabilities
	Maturity		Maturity
Source of Fair Value	< 1 Year		1 - 3 Years		Total
Prices Actively Quoted (NYMEX)	$	1,287	$	179	$	1,466
Prices Provided by Other External Sources (Basis)	—		$	—	—
Prices based on internal models or other valuable methods	319		—		319
Total	$	1,606	$	179	$	1,785

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 6.5 MMdt with a weighted-average settlement price of $3.97 per dt.  Contracted volumes of our Basis contracts are 0.0 MMdt with a weighted average settlement price of $(1.02) per dt.

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

Net Derivatives — Energy Related Liability, January 1, 2013	$	(1,929	)
Contracts Settled During the Nine Months ended September 30, 2013, Net	2,142
Other Changes in Fair Value from Continuing and New Contracts, Net	(1,692		)
Net Derivatives — Energy Related Liability, September 30, 2013	$	(1,479	)

Interest Rate Risk - Our exposure to interest rate risk relates primarily to short-term, variable-rate borrowings. Short-term, variable-rate debt outstanding at September 30, 2013, was $110.0 million and averaged $90.5 million during the first nine months of 2013. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $0.5 million increase in our annual interest expense, net of tax. The 100 basis point increase was chosen for illustrative purposes, as it provides a simple basis for calculating the impact of interest rate changes under a variety of interest rate scenarios. Over the past five years, the change in basis points (b.p.) of our average monthly interest rates from the beginning to end of each year was as follows: 2012 - 1 b.p. decrease; 2011 - 14 b.p. decrease; 2010 – 5 b.p. increase; 2009 – 29 b.p. decrease; and 2008 - 317 b.p. decrease.  As of September 30, 2013, our average interest rate on variable-rate debt was 0.34%.

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 September 30, 2013, the interest costs on all 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.

30

As of September 30, 2013, SJG’s active interest rate swaps were as follows:

Amount		Fixed Interest Rate		Start Date	Maturity	Type
$	12,500,000	3.43	%	12/1/2006	2/1/2036	Tax-exempt
$	12,500,000	3.43	%	12/1/2006	2/1/2036	Tax-exempt

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

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

Changes in Internal Control Over Financial Reporting

There has not been any change in SJG’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 September 30, 2013 that has materially affected, or is reasonably likely to materially affect, SJG’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 29.

Item 1A. Risk Factors

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

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

31

Item 6. Exhibits

(a)           Exhibits

Exhibit No.	Description
31.1	Certification of Principal Executive Officer Pursuant to Rule 13a-14(a) of the Exchange Act.
31.2	Certification of Principal Financial Officer Pursuant to Rule 13a-14(a) of the Exchange Act.
32.1	Certification of Principal 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 Principal 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 Gas’ Quarterly Report on Form 10-Q for the three and nine months ended September 30, 2013, filed with the Securities and Exchange Commission on November 12, 2013 formatted in XBRL (eXtensible Business Reporting Language): (i) the Condensed Statements of Income; (ii) the Condensed Statements of Comprehensive Income; (iii) the Condensed Statements of Cash Flows; (iv) the Condensed Balance Sheets and (v) the Notes to Condensed Financial Statements.

32

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 GAS COMPANY

(Registrant)

Dated:	November 12, 2013	By:	/s/ Jeffrey E. DuBois
			Jeffrey E. DuBois
			President
			(Principal Executive Officer)
Dated:	November 12, 2013	By:	/s/ Stephen H. Clark
			Stephen H. Clark
			Senior Vice President - Regulatory Affairs and Treasurer
			(Principal Financial Officer)
Dated:	November 12, 2013	By:	/s/ Thomas S. Kavanaugh
			Thomas S. Kavanaugh
			Controller

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EX-31.1

Exhibit 31.1

CERTIFICATION

I, Jeffrey E. DuBois, certify that:

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

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

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

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

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

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

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

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

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

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

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

		South Jersey Gas Company
Date:	November 12, 2013	By:	/s/ Jeffrey E. DuBois
			Jeffrey E. DuBois
			President
			(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Stephen H. Clark, certify that:

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

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

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

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

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

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

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

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

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

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

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

		South Jersey Gas Company
Date:	November 12, 2013	By:	/s/ Stephen H. Clark
			Stephen H. Clark
			Senior Vice President - Regulatory Affairs and Treasurer
			(Principal Financial Officer)

EX-32.1

Exhibit 32.1

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

AS ADOPTED PURSUANT TO SECTION 906 OF

THE SARBANES-OXLEY ACT OF 2002

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

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

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

/s/ Jeffrey E. DuBois

Name:  Jeffrey E. DuBois

Title:  President

(Principal Executive Officer)

November 12, 2013

EX-32.2

Exhibit 32.2

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

AS ADOPTED PURSUANT TO SECTION 906 OF

THE SARBANES-OXLEY ACT OF 2002

In connection with the filing of the Quarterly Report on Form 10-Q of South Jersey Gas Company (the “Company”) for the period ended September 30, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Stephen H. Clark, Senior Vice President - Regulatory Affairs and Treasurer (Principal Financial Officer) of the Company, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

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

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

/s/ Stephen H. Clark

Name:  Stephen H. Clark

Title:  Senior Vice President - Regulatory Affairs and Treasurer

(Principal Financial Officer)

November 12, 2013

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DERIVATIVE INSTRUMENTS

9 Months Ended

Sep. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS:

SJG is involved in buying, selling, transporting and storing natural gas and is subject to market risk on expected future purchases and sales due to commodity price fluctuations. The Company, through its affiliate South Jersey Resources Group (SJRG) and another counterparty, 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, futures contracts, swap agreements and options contracts. As of September 30, 2013, SJG had outstanding derivative contracts intended to limit the exposure to market risk on 6.5 MMdts of expected future purchases of natural gas. These contracts, which do not qualify for the normal purchase and sale exemption and 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 balance sheets. The costs or benefits of these short-term contracts are recoverable through SJG’s Basic Gas Supply Service (BGSS) clause, subject to BPU approval. As a result, the net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Regulatory Assets or Regulatory Liabilities on the condensed balance sheets. As of September 30, 2013 and December 31, 2012, SJG had $1.5 million and $1.9 million of unrealized losses, respectively, included in its BGSS related to open financial contracts.

The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives-Other on the condensed balance sheets. The fair value represents the amount SJG would have to pay the counterparty to terminate these contracts as of those dates. There have been no significant changes to the Company’s active interest rate swaps since December 31, 2012 which are described in Note 1 to the Financial Statements in Item 8 of SJG’s Annual Report on Form 10-K as of December 31, 2012. Subject to BPU approval, the market value upon termination of these interest rate derivatives can be recovered in rates and, therefore, these unrealized losses have been included in Regulatory Assets on the condensed balance sheets.

We previously used derivative transactions known as “Treasury Locks” to hedge against the impact on our cash flows of possible interest rate increases on debt issued in September 2005.  The initial $1.4 million cost of the Treasury Locks has been included in Accumulated Other Comprehensive Loss and is being amortized over the 30 year life of the associated debt issue.  As of September 30, 2013 and December 31, 2012, the unamortized balance was approximately $1.0 million and $1.1 million, respectively.

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

Derivatives not designated as hedging instruments under GAAP	September 30, 2013				December 31, 2012
	Assets		Liabilities		Assets		Liabilities
Energy related commodity contracts:
Derivatives – Energy Related – Current	$	239	$	1,606	$	464	$	2,615
Derivatives – Energy Related – Non-Current	67		179		302		80
Interest rate contracts:
Derivatives – Other	—		4,569		—		7,761
Total derivatives not designated as hedging instruments under GAAP	306		6,354		766		10,456
Total Derivatives	$	306	$	6,354	$	766	$	10,456

For derivative instruments disclosed in the table above, information as to the presentation on the condensed balance sheets is as follows (in thousands):

As of September 30, 2013
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	306		$	—	$	306		$	(306	)	(A)	$	—	$	—
Derivatives - Energy Related Liabilities	(1,785		)	—		(1,785		)	306			(B)	1,160		(319		)
Derivatives - Other	(4,569		)	—		(4,569		)	—				—		(4,569		)

As of December 31, 2012
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	766		$	—	$	766		$	(447	)	(A)	$	—	$	319
Derivatives - Energy Related Liabilities	(2,695		)	—		(2,695		)	447			(B)	1,136		(1,112		)
Derivatives - Other	(7,761		)	—		(7,761		)	—				—		(7,761		)

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

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

The effect of derivative instruments on the condensed statements of income for the three and nine months ended September 30, 2013 and 2012 are as follows (in thousands):

	Three months ended September 30,						Nine months ended September 30,
Derivatives in Cash Flow Hedging Relationships	2013			2012			2013			2012
Interest Rate Contracts:
Losses reclassified from accumulated OCL into income (a)	$	(12	)	$	(12	)	$	(36	)	$	(36	)

(a) Included in Interest Charges

Net realized losses of $0.4 million and $3.0 million associated with SJG's energy related financial commodity contracts for the three months ended September 30, 2013 and 2012 and losses of $0.6 million and $13.7 million for the nine months ended September 30, 2013 and 2012, 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.

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CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Statement of Cash Flows [Abstract]
Net Cash Provided by Operating Activities	$ 109,974	$ 51,006
Cash Flows from Investing Activities:
Capital Expenditures	(118,383)	(114,886)
Net (Purchase) Sale of Restricted Investments in Margin Accounts	(809)	641
Investment in Long-Term Receivables	(5,012)	(4,178)
Proceeds from Long-Term Receivables	5,376	5,217
Net Cash Used in Investing Activities	(118,828)	(113,206)
Cash Flows from Financing Activities:
Net Borrowing from Short-Term Credit Facilities	7,900	11,300
Proceeds from Issuance of Long-Term Debt	0	85,000
Principal Repayments of Long-Term Debt	(25,000)	(35,000)
Premium for Early Retirement of Debt	0	(700)
Payments for Issuance of Long-Term Debt	(30)	(936)
Additional Investment by Shareholder	25,000	0
Net Cash Provided by Financing Activities	7,870	59,664
Net Decrease in Cash and Cash Equivalents	(984)	(2,536)
Cash and Cash Equivalents at Beginning of Period	2,678	3,504
Cash and Cash Equivalents at End of Period	$ 1,694	$ 968

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REGULATORY ASSETS AND LIABILITIES

9 Months Ended

Sep. 30, 2013

Regulatory Assets and Liabilities Disclosure [Abstract]

REGULATORY ASSETS AND LIABILITIES

REGULATORY ASSETS AND LIABILITIES:

There have been no significant changes to the nature of SJG’s regulatory assets and liabilities since December 31, 2012, which are described in Notes 3 and 4 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012.

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

	September 30, 2013		December 31, 2012
Environmental Remediation Costs:
Expended - Net	$	30,189	$	37,892
Liability for Future Expenditures	108,236		107,410
Deferred Asset Retirement Obligation Costs	30,607		30,199
Deferred Pension and Other Postretirement Benefit Costs	95,897		95,897
Conservation Incentive Program Receivable	12,573		31,686
Societal Benefit Costs Receivable	12,816		12,801
Premium for Early Retirement of Debt	976		1,075
Deferred Interest Rate Contracts (Note 11)	4,569		7,761
Energy Efficiency Tracker	12,263		12,306
Pipeline Supplier Service Charges	7,522		8,771
Other Regulatory Assets	11,079		6,858
Total Regulatory Assets	$	326,727	$	352,656

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

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

	September 30, 2013		December 31, 2012
Excess Plant Removal Costs	$	41,128	$	45,593
Deferred Revenues-Net	8,352		10,924
Other Regulatory Liabilities	2,739		—
Total Regulatory Liabilities	$	52,219	$	56,517

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

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REGULATORY ASSETS AND LIABILITIES (Tables)

9 Months Ended

Sep. 30, 2013

Regulatory Assets and Liabilities Disclosure [Abstract]

Schedule of Regulatory Assets

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

	September 30, 2013		December 31, 2012
Environmental Remediation Costs:
Expended - Net	$	30,189	$	37,892
Liability for Future Expenditures	108,236		107,410
Deferred Asset Retirement Obligation Costs	30,607		30,199
Deferred Pension and Other Postretirement Benefit Costs	95,897		95,897
Conservation Incentive Program Receivable	12,573		31,686
Societal Benefit Costs Receivable	12,816		12,801
Premium for Early Retirement of Debt	976		1,075
Deferred Interest Rate Contracts (Note 11)	4,569		7,761
Energy Efficiency Tracker	12,263		12,306
Pipeline Supplier Service Charges	7,522		8,771
Other Regulatory Assets	11,079		6,858
Total Regulatory Assets	$	326,727	$	352,656

Schedule of Regulatory Liabilities

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

	September 30, 2013		December 31, 2012
Excess Plant Removal Costs	$	41,128	$	45,593
Deferred Revenues-Net	8,352		10,924
Other Regulatory Liabilities	2,739		—
Total Regulatory Liabilities	$	52,219	$	56,517

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LONG-TERM DEBT

9 Months Ended

Sep. 30, 2013

Long-term Debt, Unclassified [Abstract]

LONG-TERM DEBT

LONG-TERM DEBT:

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

During the third quarter of 2013, SJG redeemed at par $10.5 million of 4.46% MTN's issued in July 2003 and $14.5 million of 5.027% MTN's issued in September 2003.

In September 2013, SJG agreed in principle to issue $80.0 million of MTN's under a private placement. SJG expects to issue $50.0 million of 4.01% MTN's in November 2013, due November 2030, and $30.0 million of 4.23% MTN's in January 2014, due January 2030.

We retire debt when it is cost effective as permitted by the debt agreements.  Our long-term debt agreements contain no financial covenants.

The Company did not issue any long-term debt during the nine months ended September 30, 2013.

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ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	$ (13,568)	[1]			$ (13,285)	[1]
Other comprehensive income before reclassifications	221				413
Amounts reclassified from AOCL	7	[2]			(468)	[2]
Other Comprehensive (Loss) Gain - Net of Tax	228	[1]	212	[1]	(55)	[1]	441	[1]
Ending balance	(13,340)	[1]			(13,340)	[1]
Combined statutory tax rate	41.00%		41.00%		41.00%		41.00%
Postretirement Liability Adjustment [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	(12,958)	[1]			(12,958)	[1]
Other comprehensive income before reclassifications	0				0
Amounts reclassified from AOCL	0	[2]			0	[2]
Other Comprehensive (Loss) Gain - Net of Tax	0				0
Ending balance	(12,958)	[1]			(12,958)	[1]
Unrealized Gain (Loss) on Derivatives-Other [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	(607)	[1]			(621)	[1]
Other comprehensive income before reclassifications	0				0
Amounts reclassified from AOCL	7	[2]			21	[2]
Other Comprehensive (Loss) Gain - Net of Tax	7				21
Ending balance	(600)	[1]			(600)	[1]
Unrealized Gain (Loss) on Available-for-Sale Securities [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	(3)	[1]			294	[1]
Other comprehensive income before reclassifications	221				413
Amounts reclassified from AOCL	0	[2]			(489)	[2]
Other Comprehensive (Loss) Gain - Net of Tax	221				(76)
Ending balance	$ 218	[1]			$ 218	[1]

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

[2] See table below.

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UNUSED LINES OF CREDIT (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Line of Credit Facility [Line Items]
Total Facility	$ 210,000,000
Usage	110,000,000
Available Liquidity	100,000,000
Average borrowings outstanding during the period	90,500,000	146,300,000
Maximum amounts outstanding during the period	119,900,000	180,500,000
Weighted average borrowing cost	0.34%	0.47%
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Total Facility	200,000,000
Usage	110,000,000
Available Liquidity	90,000,000
Expiration Date	May 2018
Uncommitted Bank Lines [Member]
Line of Credit Facility [Line Items]
Total Facility	10,000,000
Usage	0
Available Liquidity	10,000,000
Expiration Date	August 2014
South Jersey Gas Commercial Paper Program [Member]
Line of Credit Facility [Line Items]
Total Facility	$ 200,000,000
Fixed maturities of notes, at maximum number of days (in days)	270 days
Minimum [Member]
Line of Credit Facility [Line Items]
Financial covenant, ratio of indebtedness to consolidated total capitalization minimum	0.65

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PENSION AND OTHER POSTRETIREMENT BENEFITS (Tables)

9 Months Ended

Sep. 30, 2013

Compensation and Retirement Disclosure [Abstract]

Schedule of defined benefit plans disclosures

For the three and nine months ended  September 30, 2013 and 2012, net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):

	Pension Benefits						Pension Benefits
	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
Service Cost	$	1,040		$	873		$	3,120		$	2,619
Interest Cost	1,811			1,853			5,434			5,559
Expected Return on Plan Assets	(2,286		)	(1,991		)	(6,859		)	(5,974		)
Amortizations:
Prior Service Cost	48			48			144			145
Actuarial Loss	1,729			1,469			5,185			4,407
Net Periodic Benefit Cost	2,342			2,252			7,024			6,756
Capitalized Benefit Costs	(1,218		)	(1,306		)	(3,653		)	(3,513		)
Total Net Periodic Benefit Expense	$	1,124		$	946		$	3,371		$	3,243

	Other Postretirement Benefits						Other Postretirement Benefits
	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
Service Cost	$	212		$	198		$	637		$	594
Interest Cost	509			573			1,526			1,719
Expected Return on Plan Assets	(443		)	(402		)	(1,329		)	(1,206		)
Amortizations:
Prior Service Credits	(53		)	(54		)	(159		)	(162		)
Actuarial Loss	324			329			972			988
Net Periodic Benefit Cost	549			644			1,647			1,933
Capitalized Benefit Costs	(285		)	(374		)	(856		)	(1,005		)
Total Net Periodic Benefit Expense	$	264		$	270		$	791		$	928

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UNUSED LINES OF CREDIT (Tables)

9 Months Ended

Sep. 30, 2013

Line of Credit Facility [Abstract]

Schedule of lines of credit

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

	Total Facility		Usage		Available Liquidity		Expiration Date
Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	110,000	$	90,000	May 2018
Uncommitted Bank Lines	10,000		—		10,000		August 2014
Total	$	210,000	$	110,000	$	100,000

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DERIVATIVE INSTRUMENTS 4 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Losses reclassified from accumulated OCI into income	$ (12)	[1]	$ (12)	[1]	$ (36)	[1]	$ (36)	[1]

[1] Included in Interest Charges

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REGULATORY ASSETS AND LIABILITIES (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Regulatory Assets [Line Items]
Total regulatory assets	$ 326,727	$ 352,656
Environmental Restoration Costs: Expended - Net [Member]
Regulatory Assets [Line Items]
Total regulatory assets	30,189	37,892
Environmental Restoration Costs: Liability for Future Expenditures [Member]
Regulatory Assets [Line Items]
Total regulatory assets	108,236	107,410
Deferred Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets	30,607	30,199
Deferred Pension and Other Postretirement Benefit Costs [Member]
Regulatory Assets [Line Items]
Total regulatory assets	95,897	95,897
Conservation Incentive Program Receivable [Member]
Regulatory Assets [Line Items]
Total regulatory assets	12,573	31,686
Societal Benefit Costs Receivable [Member]
Regulatory Assets [Line Items]
Total regulatory assets	12,816	12,801
Premium for Early Retirement of debt [Member]
Regulatory Assets [Line Items]
Total regulatory assets	976	1,075
Deferred Interest Rate Contracts [Member]
Regulatory Assets [Line Items]
Total regulatory assets	4,569	7,761
Energy Efficiency Tracker [Member]
Regulatory Assets [Line Items]
Total regulatory assets	12,263	12,306
Pipeline Supplier Service Charges [Member]
Regulatory Assets [Line Items]
Total regulatory assets	7,522	8,771
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Total regulatory assets	$ 11,079	$ 6,858

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COMMITMENTS AND CONTINGENCIES (Details) (USD $)	9 Months Ended
	Sep. 30, 2013 unions sites	Dec. 31, 2012
Loss Contingencies [Line Items]
Letter of credit provided	$ 210,000,000
Number of sites for environmental cleanup	12
Monthly gas supply related demand charges and reservation fees	4,300,000
Estimated litigation liability	400,000	500,000
Percentage of personnel represented in collective bargaining agreements	60.00%
Number of unions	2
Standby Letter of Credit [Member]
Loss Contingencies [Line Items]
Letter of credit provided	$ 25,200,000

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ACCUMULATED OTHER COMPREHENSIVE LOSS 2 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended			9 Months Ended
	Sep. 30, 2013		Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	$ (2,629)		$ (3,872)	$ (8,379)		$ (11,832)
Other Income and Expense	764		1,703	3,024		4,482
Income Before Income Taxes	1,420		781	63,794		61,920
Income Taxes	(471)		(258)	(23,511)		(23,122)
Net Income	949		523	40,283		38,798
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Income Before Income Taxes	12			(792)
Income Taxes	(5)	[1]		324	[1]
Net Income	7			(468)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Gain (Loss) on Derivatives-Other [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Interest Charges	12			36
Reclassification out of Accumulated Other Comprehensive Income [Member] | Unrealized Gain (Loss) on Available-for-Sale Securities [Member]
Reclassification out of Accumulated Other Comprehensive Income [Line Items]
Other Income and Expense	$ 0			$ (828)

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

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Accounting Policies [Abstract]
Amount of Transitional Energy Facility Assessment and Public Utilities Assessment included in revenues and cost of sales	$ 0.5	$ 0.7	$ 3.4	$ 4.0
Decrease in TEFA revenue based tax rate	25.00%		25.00%		25.00%

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DERIVATIVE INSTRUMENTS (Details) (USD $)	1 Months Ended			3 Months Ended				9 Months Ended
	Sep. 30, 2005	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013 South Jersey Resource Group [Member]		Sep. 30, 2012 South Jersey Resource Group [Member]		Sep. 30, 2013 South Jersey Resource Group [Member]		Sep. 30, 2012 South Jersey Resource Group [Member]		Sep. 30, 2013 Natural Gas (in MMdts) [Member] Derivative Transaction Type, Purchase [Member] millions_of_decatherms
Derivative [Line Items]
Outstanding derivative contracts notional amount												6.5
Unrealized gains (losses) included in its BGSS related to open financial contracts		$ 1,500,000	$ (1,900,000)
Initial cost of Treasury Locks	1,400,000
Amortization period of Treasury Locks	30 years
Unamortized balance of Treasury Locks		1,000,000	1,100,000
Net realized losses associated with SJG's energy-related financial commodity contracts				$ 389,000	[1]	$ 3,011,000	[1]	$ 568,000	[1]	$ 13,666,000	[1]

[1] Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.

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RELATED PARTY TRANSACTIONS (Tables)

9 Months Ended

Sep. 30, 2013

Related Party Transactions [Abstract]

Summary of related party transactions

A summary of related party transactions, excluding pass-through items, included in Operating Revenues were as follows, (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013		2012
Operating Revenues/Affiliates:
SJRG	$	344	$	211	$	1,194	$	483
Other	335		312		974		499
Total Operating Revenue/Affiliates	$	679	$	523	$	2,168	$	982

Related party transactions, excluding pass-through items, included in Operating Expenses were as follows, (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013		2012
Costs of Sales/Affiliates (Excluding depreciation):
SJRG	$	5,436	$	2,683	$	11,105	$	8,445
Energy-Related Derivative (Gains) / Losses *
SJRG	$	389	$	3,011	$	568	$	13,666

* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.

Operations Expense/Affiliates
SJI	$	2,737		$	2,237		$	8,613		$	7,400
SJIS	1,330			1,240			4,264			3,833
Millennium	665			796			2,014			2,379
Other	(103		)	(99		)	(336		)	(377		)
Total Operations Expense/Affiliates	$	4,629		$	4,174		$	14,555		$	13,235

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CONDENSED BALANCE SHEETS (UNAUDITED) (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]
Common Stock, Par Value (in dollars per share)	$ 2.50	$ 2.50
Authorized (in shares)	4,000,000	4,000,000
Outstanding (in shares)	2,339,139	2,339,139

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STOCK-BASED COMPENSATION PLANS

9 Months Ended

Sep. 30, 2013

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

STOCK-BASED COMPENSATION PLANS

STOCK-BASED COMPENSATION PLANS:

Officers and other key employees of SJG participate in the Stock Option, Stock Appreciation Rights and Restricted Stock Award Plan ("Plan") of SJI. Restricted shares issued under this plan vest over a three-year period and are subject to SJI achieving certain market or earnings-based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 150% of the original share units granted. Grants containing market-based

performance targets have been issued in each of the last three years and use SJI's total shareholder return (TSR) relative to a peer group to measure performance. Beginning with 2012, grants containing earnings-based targets have also been issued. These new grants are based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance.

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

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

Grant Date	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Jan. 2011 - TSR	7,116	$	50.94	27.5	%	1.01	%
Jan. 2012 - TSR	3,533	$	51.23	22.5	%	0.43	%
Jan. 2012 - EPS	3,533	$	56.93	n/a		n/a
Jan. 2013 - TSR	4,001	$	44.38	21.1	%	0.40	%
Jan. 2013 - EPS	4,001	$	51.18	n/a		n/a

Expected volatility is based on the actual volatility of SJI’s share price over the preceding three year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three year term of the restricted shares. As notional dividend equivalents are credited to the holders, which are reinvested during the three year service period, no reduction to the fair value of the award is required.

The cost for restricted stock awards during 2013 and 2012 is approximately $0.1 million per quarter.

As of September 30, 2013, there was $0.5 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 1.8 years.

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

	Shares		Weighted Average Grant Date Fair Value
Nonvested Shares Outstanding, January 1, 2013	15,108		$	52.55
Granted	9,324		$	47.78
Canceled / Forfeited	(2,248	)	$	50.02
Nonvested Shares Outstanding, September 30, 2013	22,184		$	50.80

During the nine months ended September 30, 2013, SJI awarded 12,901 shares that had vested at December 31, 2012, to SJG's officers and other key employees at a market value of $0.6 million. During the nine months ended September 30, 2012, SJI awarded 7,098 shares at a market value of $0.4 million to SJG's officers and other key employees. SJG has a policy of making cash payments to SJI to satisfy its obligations under this plan. Cash payments to SJI during each of the nine months ended September 30, 2013 and 2012 were approximately $0.4 million relating to stock awards. Additionally, a change in control could result in the nonvested shares becoming nonforfeitable or immediately payable in cash.

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RELATED PARTY TRANSACTIONS

9 Months Ended

Sep. 30, 2013

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS:

There have been no significant changes in the nature of SJG’s related party transactions since December 31, 2012. See Note 5 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012 for a detailed description of such transactions.

A summary of related party transactions, excluding pass-through items, included in Operating Revenues were as follows, (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013		2012
Operating Revenues/Affiliates:
SJRG	$	344	$	211	$	1,194	$	483
Other	335		312		974		499
Total Operating Revenue/Affiliates	$	679	$	523	$	2,168	$	982

Related party transactions, excluding pass-through items, included in Operating Expenses were as follows, (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013		2012
Costs of Sales/Affiliates (Excluding depreciation):
SJRG	$	5,436	$	2,683	$	11,105	$	8,445
Energy-Related Derivative (Gains) / Losses *
SJRG	$	389	$	3,011	$	568	$	13,666

* Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.

Operations Expense/Affiliates
SJI	$	2,737		$	2,237		$	8,613		$	7,400
SJIS	1,330			1,240			4,264			3,833
Millennium	665			796			2,014			2,379
Other	(103		)	(99		)	(336		)	(377		)
Total Operations Expense/Affiliates	$	4,629		$	4,174		$	14,555		$	13,235

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RATES AND REGULATORY ACTIONS

9 Months Ended

Sep. 30, 2013

Public Utilities, General Disclosures [Abstract]

RATES AND REGULATORY ACTIONS

RATES AND REGULATORY ACTIONS:

SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). In January 2013, SJG credited the accounts of our periodic Basic Gas Supply Service (BGSS) customers with refunds totaling $9.4 million due to gas costs that were lower than projected.

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

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

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

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

In May 2013, SJG made its annual BGSS and CIP filing requesting a $17.9 million decrease in annual revenues. Provisional rates were approved by the BPU in September 2013 and effective October 1, 2013.

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

In October 2012, SJG filed a petition requesting a $13.2 million increase in annual revenues by rolling $110.6 million of CIRT I, II and III investments into base rates. In May 2013, SJG filed a supplemental petition requesting to roll an additional $6.9 million of CIRT III investments into base rates, for a total annual revenue increase of $15.5 million related to $117.5 million of CIRT investments made since our last base rate case in 2010. The BPU approved the petition in September 2013 with rates effective October 1, 2013.

In September 2013, SJG filed a petition requesting a Storm Hardening and Reliability Program (SHARP), pursuant to which SJG is proposing to invest approximately $280 million over seven years to replace low pressure distribution mains and services with high pressure distribution mains and services in coastal areas that are susceptible to flooding during major storm events. This petition is currently pending.

There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2012. See Note 3 to the Financial Statements in Item 8 of SJG's Form 10-K as of December 31, 2012.

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Total [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Total [Member]		Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 1 [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 1 [Member]		Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 2 [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 2 [Member]		Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Level 3 [Member]		Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Level 3 [Member]
Assets [Abstract]
Available-for-sale Securities			$ 8,237	[1]	$ 7,520	[1]	$ 8,237	[1]	$ 769	[1]	$ 0	[1]	$ 6,751	[1]	$ 0	[1]	$ 0	[1]
Derivatives - Energy Related Assets			306	[2]	766	[2]	306	[2]	447	[2]	0	[2]	319	[2]	0	[2]	0	[2]
Total Assets			8,543		8,286		8,543		1,216		0		7,070		0		0
Liabilities [Abstract]
Derivatives - Energy Related Liabilities			1,785	[2]	2,695	[2]	1,466	[2]	2,694	[2]	0	[2]	1	[2]	319	[2]	0	[2]
Derivatives - Other			4,569	[3]	7,761	[3]	0	[3]	0	[3]	4,569	[3]	7,761	[3]	0	[3]	0	[3]
Total Liabilities			6,354		10,456		1,466		2,694		4,569		7,762		319		0
Changes in significant unobservable inputs [Roll forward]
Balance at beginning of period	(243)	0
Total losses unrealized in Regulatory Liabilities (see note 4)	(76)	(319)
Settlements	0	0
Total activity	(76)	(319)
Balance at end of period	$ (319)	$ (319)

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

[2] Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. 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. 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. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

[3] Derivatives – Other, include interest rate swaps that 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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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES (Tables)

9 Months Ended

Sep. 30, 2013

Fair Value Disclosures [Abstract]

Fair value of assets and liabilities

For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands):

As of September 30, 2013
	Total		Level 1		Level 2		Level 3
Assets -
Available-for-Sale Securities (A)	$	8,237	$	8,237	$	—	$	—
Derivatives – Energy Related Assets (B)	306		306		—		—
	$	8,543	$	8,543	$	—	$	—
Liabilities -
Derivatives – Energy Related Liabilities (B)	$	1,785	$	1,466	$	—	$	319
Derivatives – Other (C)	4,569		—		4,569		—
	$	6,354	$	1,466	$	4,569	$	319

As of December 31, 2012
	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,520	$	769	$	6,751	$	—
Derivatives - Energy Related Assets (B)	766		447		319		—
	$	8,286	$	1,216	$	7,070	$	—
Liabilities
Derivatives - Energy Related Liabilities (B)	$	2,695	$	2,694	$	1	$	—
Derivatives - Other (C)	7,761		—		7,761		—
	$	10,456	$	2,694	$	7,762	$	—

(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 consisted of funds that are not publicly traded.  These funds, which consisted 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. 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. 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. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.

Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

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

Quantitative information regarding significant unobservable inputs in Level 3 fair value measurements

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

Type	Fair Value at September 30, 2013		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$—	$319	Discounted Cash Flow	Forward price (per dt)	$(1.75) - $(1.75) [$(1.75)]

Changes in fair value of significant unobservable inputs

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

	Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
Balance at beginning of period	$	(243	)	$	—
Total losses unrealized in Regulatory Liabilities (see note 4)	(76		)	(319		)
Settlements	—			—
	(76		)	(319		)
Balance at September 30	$	(319	)	$	(319	)

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STOCK-BASED COMPENSATION PLANS (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	22,184		22,184
Fair Value Per Share (in dollars per share)	$ 50.80		$ 50.80
Vesting period of shares			3 years	3 years
Cost of Restricted Stock Awards	$ 0.1	$ 0.1
Unrecognized compensation cost of awards granted under the plan	0.5		0.5
Weighted average period over which unrecognized compensation cost is to be recognized (in years)			1 year 9 months 18 days
Shares [Roll Forward]
Nonvested Shares Outstanding, beginning balance (in shares)			15,108
Granted (in shares)			9,324
Canceled / Forfeited (in shares)			(2,248)
Nonvested Shares Outstanding, ending balance (in shares)	22,184		22,184
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, beginning balance (in dollars per share)			$ 52.55
Weighted Average Grant Date Fair Value, Granted (in dollars per share)			$ 47.78
Weighted Average Grant Date Fair Value, Canceled / Forfeited (in dollars per share)			$ 50.02
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$ 50.80		$ 50.80
Number of shares awarded during the period			12,901	7,098
Market value of shares awarded			0.6	0.4
Cash payments to SJI relating to stock awards			$ 0.4	$ 0.4
Grant Date January 2011 - TSR [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	7,116		7,116
Fair Value Per Share (in dollars per share)	$ 50.94		$ 50.94
Expected Volatility			27.50%
Risk-Free Interest Rate			1.01%
Shares [Roll Forward]
Nonvested Shares Outstanding, ending balance (in shares)	7,116		7,116
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$ 50.94		$ 50.94
Grant Date January 2012 - TSR [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	3,533		3,533
Fair Value Per Share (in dollars per share)	$ 51.23		$ 51.23
Expected Volatility			22.50%
Risk-Free Interest Rate			0.43%
Shares [Roll Forward]
Nonvested Shares Outstanding, ending balance (in shares)	3,533		3,533
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$ 51.23		$ 51.23
Grant Date January 2012 - EPS [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	3,533		3,533
Fair Value Per Share (in dollars per share)	$ 56.93		$ 56.93
Shares [Roll Forward]
Nonvested Shares Outstanding, ending balance (in shares)	3,533		3,533
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$ 56.93		$ 56.93
Grant Date January 2013 - TSR [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	4,001		4,001
Fair Value Per Share (in dollars per share)	$ 44.38		$ 44.38
Expected Volatility			21.10%
Risk-Free Interest Rate			0.40%
Shares [Roll Forward]
Nonvested Shares Outstanding, ending balance (in shares)	4,001		4,001
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$ 44.38		$ 44.38
Grant Date January 2013 - EPS [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Shares Outstanding (in shares)	4,001		4,001
Fair Value Per Share (in dollars per share)	$ 51.18		$ 51.18
Shares [Roll Forward]
Nonvested Shares Outstanding, ending balance (in shares)	4,001		4,001
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Nonvested Shares Outstanding, ending balance (in dollars per share)	$ 51.18		$ 51.18
Minimum [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted			0.00%
Maximum [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Percentage of actual amount of shares that ultimately vest of original share units granted			150.00%

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FINANCIAL INSTRUMENTS (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Schedule of Financial Instruments [Line Items]
Restricted investments held in escrow	$ 0.1	$ 0.1
Margin accounts with selected counterparties to support risk management activities	0.9	1.1
Restricted investments, energy-related contracts	1.0
Estimated fair value of long-term debt	446.2	502.0
Carrying amount of long-term debt	425.0	450.0
Financing Receivable [Member]
Schedule of Financial Instruments [Line Items]
Long-term receivables, net of unamortized discount	14.0	13.6
Imputed interest	$ 1.3	$ 1.3

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EQUITY CONTRIBUTIONS (Details) (USD $) In Thousands, unless otherwise specified	1 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012
Equity [Abstract]
Additional Investment from SJI	$ 25,000	$ 25,000	$ 0

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DERIVATIVE INSTRUMENTS DERIVATIVE INSTRUMENTS 3 (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Commodity Contract [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets/liabilities	$ 306		$ 766
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	306		766
Gross amounts not offset in the balance sheet, Financial Instruments	(306)	[1]	(447)	[1]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		0
Net amount	0		319
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(1,785)		(2,695)
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	(1,785)		(2,695)
Gross amounts not offset in the balance sheet, Financial Instruments	306	[2]	447	[2]
Gross amounts not offset in the balance sheet, Cash Collateral Posted	1,160		1,136
Net amount	(319)		(1,112)
Interest Rate Contract [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts of recognized assets/liabilities	(4,569)		(7,761)
Gross amount offset in the balance sheet	0		0
Net amounts of assets/liabilities in balance sheet	(4,569)		(7,761)
Gross amounts not offset in the balance sheet, Financial Instruments	0		0
Gross amounts not offset in the balance sheet, Cash Collateral Posted	0		0
Net amount	$ (4,569)		$ (7,761)

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

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

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CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Statement of Other Comprehensive Income [Abstract]
Net Income	$ 949		$ 523		$ 40,283		$ 38,798
Other Comprehensive (Loss) Gain - Net of Tax:
Unrealized (Loss) Gain on Available-for-Sale Securities	221	[1]	205	[1]	(76)	[1]	420	[1]
Unrealized Gain on Derivatives - Other	7	[1]	7	[1]	21	[1]	21	[1]
Other Comprehensive (Loss) Gain - Net of Tax	228	[1]	212	[1]	(55)	[1]	441	[1]
Comprehensive Income	$ 1,177		$ 735		$ 40,228		$ 39,239
Combined statutory tax rate	41.00%		41.00%		41.00%		41.00%

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

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PENSION AND OTHER POSTRETIREMENT BENEFITS

9 Months Ended

Sep. 30, 2013

Compensation and Retirement Disclosure [Abstract]

PENSION AND OTHER POSTRETIREMENT BENEFITS

PENSION AND OTHER POSTRETIREMENT BENEFITS:

For the three and nine months ended  September 30, 2013 and 2012, net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):

	Pension Benefits						Pension Benefits
	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
Service Cost	$	1,040		$	873		$	3,120		$	2,619
Interest Cost	1,811			1,853			5,434			5,559
Expected Return on Plan Assets	(2,286		)	(1,991		)	(6,859		)	(5,974		)
Amortizations:
Prior Service Cost	48			48			144			145
Actuarial Loss	1,729			1,469			5,185			4,407
Net Periodic Benefit Cost	2,342			2,252			7,024			6,756
Capitalized Benefit Costs	(1,218		)	(1,306		)	(3,653		)	(3,513		)
Total Net Periodic Benefit Expense	$	1,124		$	946		$	3,371		$	3,243

	Other Postretirement Benefits						Other Postretirement Benefits
	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
Service Cost	$	212		$	198		$	637		$	594
Interest Cost	509			573			1,526			1,719
Expected Return on Plan Assets	(443		)	(402		)	(1,329		)	(1,206		)
Amortizations:
Prior Service Credits	(53		)	(54		)	(159		)	(162		)
Actuarial Loss	324			329			972			988
Net Periodic Benefit Cost	549			644			1,647			1,933
Capitalized Benefit Costs	(285		)	(374		)	(856		)	(1,005		)
Total Net Periodic Benefit Expense	$	264		$	270		$	791		$	928

Capitalized benefit costs reflected in the table above relate to our construction program.

SJG contributed $9.1 million and $19.8 million to the pension plans in January 2013 and 2012, respectively. No additional contributions are expected to be made to the pension plans during 2013. Payments related to the unfunded Supplemental Executive Retirement Plan (SERP) are expected to approximate $1.2 million in 2013. We also have a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred.

See Note 11 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012 for additional information related to SJG’s pension and other postretirement benefits.

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CONDENSED BALANCE SHEETS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Property, Plant and Equipment:
Utility Plant, at original cost	$ 1,776,502		$ 1,658,790
Accumulated Depreciation	(388,511)		(373,199)
Property, Plant and Equipment - Net	1,387,991		1,285,591
Investments:
Available-for-Sale Securities	8,237		7,520
Restricted Investments	2,077		1,268
Total Investments	10,314		8,788
Current Assets:
Cash and Cash Equivalents	1,694		2,678
Accounts Receivable	50,137		49,071
Accounts Receivable - Related Parties	1,316		961
Unbilled Revenues	7,464		35,351
Provision for Uncollectibles	(5,618)		(3,985)
Natural Gas in Storage, average cost	27,753		13,896
Materials and Supplies, average cost	1,682		1,560
Deferred Income Taxes - Net	9,759		0
Prepaid Taxes	14,108		17,046
Derivatives - Energy Related Assets	239		464
Other Prepayments and Current Assets	4,644		3,343
Total Current Assets	113,178		120,385
Regulatory and Other Noncurrent Assets:
Regulatory Assets	326,727		352,656
Unamortized Debt Issuance Costs	6,282		6,663
Long-Term Receivables	9,458		9,336
Derivatives - Energy Related Assets	67		302
Other	3,170		2,738
Total Regulatory and Other Noncurrent Assets	345,704		371,695
Total Assets	1,857,187		1,786,459
Common Equity:
Common Stock, Par Value $2.50 per share: Authorized - 4,000,000 shares Outstanding - 2,339,139 shares	5,848		5,848
Other Paid-In Capital and Premium on Common Stock	226,050		201,050
Accumulated Other Comprehensive Loss	(13,340)	[1]	(13,285)	[1]
Retained Earnings	368,065		327,782
Total Common Equity	586,623		521,395
Long-Term Debt	404,000		425,000
Total Capitalization	990,623		946,395
Current Liabilities:
Notes Payable	110,000		102,100
Current Portion of Long-Term Debt	21,000		25,000
Accounts Payable - Commodity	11,682		14,926
Accounts Payable - Other	31,279		25,498
Accounts Payable - Related Parties	5,506		5,872
Derivatives - Energy Related Liabilities	1,606		2,615
Deferred Income Taxes - Net	0		10,432
Customer Deposits and Credit Balances	20,482		17,450
Environmental Remediation Costs	25,662		19,203
Taxes Accrued	1,470		1,674
Pension Benefits	1,236		1,236
Interest Accrued	4,248		6,277
Other Current Liabilities	3,331		6,492
Total Current Liabilities	237,502		238,775
Regulatory and Other Noncurrent Liabilities:
Regulatory Liabilities	52,219		56,517
Deferred Income Taxes - Net	352,845		310,357
Environmental Remediation Costs	82,574		88,207
Asset Retirement Obligations	39,645		38,892
Pension and Other Postretirement Benefits	86,431		89,193
Investment Tax Credits	424		618
Derivatives - Energy Related Liabilities	179		80
Derivatives - Other	4,569		7,761
Other	10,176		9,664
Total Regulatory and Other Noncurrent Liabilities	629,062		601,289
Commitments and Contingencies (Note 9)
Total Capitalization and Liabilities	$ 1,857,187		$ 1,786,459

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

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CONDENSED STATEMENTS OF INCOME (UNAUDITED) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Income Statement [Abstract]
Operating Revenues	$ 59,674	$ 54,251	$ 300,308	$ 292,864
Operating Expenses:
Cost of Sales (Excluding depreciation)	24,717	21,053	128,427	127,959
Operations	18,613	17,536	62,132	56,677
Maintenance	3,353	3,570	10,140	10,133
Depreciation	8,654	7,975	25,128	23,010
Energy and Other Taxes	1,052	1,167	5,332	5,815
Total Operating Expenses	56,389	51,301	231,159	223,594
Operating Income	3,285	2,950	69,149	69,270
Other Income and Expense	764	1,703	3,024	4,482
Interest Charges	(2,629)	(3,872)	(8,379)	(11,832)
Income Before Income Taxes	1,420	781	63,794	61,920
Income Taxes	(471)	(258)	(23,511)	(23,122)
Net Income	$ 949	$ 523	$ 40,283	$ 38,798

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SUBSEQUENT EVENT (Details) (Subsequent Event [Member], USD $)	1 Months Ended
	Oct. 31, 2013
Subsequent Event [Line Items]
Amount of additional debt petitioned for, period	3 years
Maximum [Member]
Subsequent Event [Line Items]
Amount of additional debt petitioned for	$ 200,000,000.0

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DERIVATIVE INSTRUMENTS (Tables)

9 Months Ended

Sep. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair value of derivative instruments

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

Derivatives not designated as hedging instruments under GAAP	September 30, 2013				December 31, 2012
	Assets		Liabilities		Assets		Liabilities
Energy related commodity contracts:
Derivatives – Energy Related – Current	$	239	$	1,606	$	464	$	2,615
Derivatives – Energy Related – Non-Current	67		179		302		80
Interest rate contracts:
Derivatives – Other	—		4,569		—		7,761
Total derivatives not designated as hedging instruments under GAAP	306		6,354		766		10,456
Total Derivatives	$	306	$	6,354	$	766	$	10,456

Offsetting assets and liabilities

For derivative instruments disclosed in the table above, information as to the presentation on the condensed balance sheets is as follows (in thousands):

As of September 30, 2013
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	306		$	—	$	306		$	(306	)	(A)	$	—	$	—
Derivatives - Energy Related Liabilities	(1,785		)	—		(1,785		)	306			(B)	1,160		(319		)
Derivatives - Other	(4,569		)	—		(4,569		)	—				—		(4,569		)

As of December 31, 2012
Description	Gross amounts of recognized assets/liabilities			Gross amount offset in the balance sheet		Net amounts of assets/liabilities in balance sheet			Gross amounts not offset in the balance sheet						Net amount
									Financial Instruments				Cash Collateral Posted
Derivatives - Energy Related Assets	$	766		$	—	$	766		$	(447	)	(A)	$	—	$	319
Derivatives - Energy Related Liabilities	(2,695		)	—		(2,695		)	447			(B)	1,136		(1,112		)
Derivatives - Other	(7,761		)	—		(7,761		)	—				—		(7,761		)

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

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

Derivatives in cash flow hedging relationships

The effect of derivative instruments on the condensed statements of income for the three and nine months ended September 30, 2013 and 2012 are as follows (in thousands):

	Three months ended September 30,						Nine months ended September 30,
Derivatives in Cash Flow Hedging Relationships	2013			2012			2013			2012
Interest Rate Contracts:
Losses reclassified from accumulated OCL into income (a)	$	(12	)	$	(12	)	$	(36	)	$	(36	)

(a) Included in Interest Charges

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STOCK-BASED COMPENSATION PLANS (Tables)

9 Months Ended

Sep. 30, 2013

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

Summary of the SJI nonvested restricted stock awards pertaining to SJG outstanding at and the assumptions used to estimate the fair value of the awards

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

Grant Date	Shares Outstanding	Fair Value Per Share		Expected Volatility		Risk-Free Interest Rate
Jan. 2011 - TSR	7,116	$	50.94	27.5	%	1.01	%
Jan. 2012 - TSR	3,533	$	51.23	22.5	%	0.43	%
Jan. 2012 - EPS	3,533	$	56.93	n/a		n/a
Jan. 2013 - TSR	4,001	$	44.38	21.1	%	0.40	%
Jan. 2013 - EPS	4,001	$	51.18	n/a		n/a

Summary of the information regarding restricted stock award activity excluding accrued dividend equivalents

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

	Shares		Weighted Average Grant Date Fair Value
Nonvested Shares Outstanding, January 1, 2013	15,108		$	52.55
Granted	9,324		$	47.78
Canceled / Forfeited	(2,248	)	$	50.02
Nonvested Shares Outstanding, September 30, 2013	22,184		$	50.80

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DERIVATIVE INSTRUMENTS 2 (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	$ 306	$ 766
Fair value Derivative Liabilities	6,354	10,456
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	306	766
Fair value Derivative Liabilities	6,354	10,456
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-Current [Member]
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	239	464
Fair value Derivative Liabilities	1,606	2,615
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Energy Related-NonCurrent [Member]
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	67	302
Fair value Derivative Liabilities	179	80
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Derivatives-Other [Member]
Derivatives, Fair Value [Line Items]
Fair value Derivative Assets	0	0
Fair value Derivative Liabilities	$ 4,569	$ 7,761

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PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) (USD $)	1 Months Ended		3 Months Ended		9 Months Ended
	Jan. 31, 2013	Jan. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Pension Benefits [Member]
Net periodic benefit cost [Abstract]
Service cost			$ 1,040,000	$ 873,000	$ 3,120,000	$ 2,619,000
Interest cost			1,811,000	1,853,000	5,434,000	5,559,000
Expected return on plan assets			(2,286,000)	(1,991,000)	(6,859,000)	(5,974,000)
Amortizations [Abstract]
Prior service cost (credits)			48,000	48,000	144,000	145,000
Actuarial loss			1,729,000	1,469,000	5,185,000	4,407,000
Net periodic benefit cost prior to capitalized benefit costs			2,342,000	2,252,000	7,024,000	6,756,000
Capitalized benefit costs			(1,218,000)	(1,306,000)	(3,653,000)	(3,513,000)
Total net periodic benefit expense			1,124,000	946,000	3,371,000	3,243,000
Contributions	9,100,000	19,800,000
Other Postretirement Benefits [Member]
Net periodic benefit cost [Abstract]
Service cost			212,000	198,000	637,000	594,000
Interest cost			509,000	573,000	1,526,000	1,719,000
Expected return on plan assets			(443,000)	(402,000)	(1,329,000)	(1,206,000)
Amortizations [Abstract]
Prior service cost (credits)			(53,000)	(54,000)	(159,000)	(162,000)
Actuarial loss			324,000	329,000	972,000	988,000
Net periodic benefit cost prior to capitalized benefit costs			549,000	644,000	1,647,000	1,933,000
Capitalized benefit costs			(285,000)	(374,000)	(856,000)	(1,005,000)
Total net periodic benefit expense			264,000	270,000	791,000	928,000
Defined benefit plan regulatory obligation to contribute to the plan during the period			3,600,000		3,600,000
Supplemental Employee Retirement Plans, Defined Benefit [Member]
Amortizations [Abstract]
Estimated future contributions			$ 1,200,000		$ 1,200,000

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REGULATORY ASSETS AND LIABILITIES REGULATORY ASSETS AND LIABILITIES 2 (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Regulatory Liabilities [Line Items]
Regulatory Liabilities	$ 52,219	$ 56,517
Excess Plant Removal Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	41,128	45,593
Deferred Revenues - Net [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	8,352	10,924
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	$ 2,739	$ 0

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RELATED PARTY TRANSACTIONS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Related Party Transaction [Line Items]
Operating Revenues/Affiliates	$ 679		$ 523		$ 2,168		$ 982
Operations Expense/Affiliates	4,629		4,174		14,555		13,235
SJRG [Member]
Related Party Transaction [Line Items]
Operating Revenues/Affiliates	344		211		1,194		483
Costs of Sales/Affiliates (Excluding depreciation)	5,436		2,683		11,105		8,445
Energy-Related Derivative (Gains) / Losses	389	[1]	3,011	[1]	568	[1]	13,666	[1]
SJI [Member]
Related Party Transaction [Line Items]
Operations Expense/Affiliates	2,737		2,237		8,613		7,400
SJIS [Member]
Related Party Transaction [Line Items]
Operations Expense/Affiliates	1,330		1,240		4,264		3,833
Millennium [Member]
Related Party Transaction [Line Items]
Operations Expense/Affiliates	665		796		2,014		2,379
Other [Member]
Related Party Transaction [Line Items]
Operating Revenues/Affiliates	335		312		974		499
Operations Expense/Affiliates	$ (103)		$ (99)		$ (336)		$ (377)

[1] Contracts used to hedge natural gas purchases. Included in Cost of Sales on the Condensed Statement of Income.

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UNUSED LINES OF CREDIT

9 Months Ended

Sep. 30, 2013

Line of Credit Facility [Abstract]

UNUSED LINES OF CREDIT

UNUSED LINES OF CREDIT:

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

	Total Facility		Usage		Available Liquidity		Expiration Date
Commercial Paper Program/ Revolving Credit Facility	$	200,000	$	110,000	$	90,000	May 2018
Uncommitted Bank Lines	10,000		—		10,000		August 2014
Total	$	210,000	$	110,000	$	100,000

The SJG facility is provided by a syndicate of banks and contains one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the credit agreement) to not more than 0.65 to 1 measured at the end of each fiscal quarter.  SJG was in compliance with this covenant as of September 30, 2013.

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

Average borrowings outstanding under these credit facilities during the nine months ended September 30, 2013 and 2012 were $90.5 million and $146.3 million, respectively.  The maximum amount outstanding under these credit facilities during the nine months ended September 30, 2013 and 2012 were $119.9 million and $180.5 million, respectively.

Based upon the existing credit facilities and a regular dialogue with our banks, we believe that there will continue to be sufficient credit available to meet our business’ future liquidity needs. Borrowings under these credit facilities are at market rates.  The weighted average interest rate on these borrowings, which changes daily, was 0.34% and 0.47% at September 30, 2013 and 2012, respectively.

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ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)

9 Months Ended

Sep. 30, 2013

Equity [Abstract]

Schedule of changes in accumulated other comprehensive loss (AOCL)

The changes in Accumulated Other Comprehensive Loss (AOCL) for the three and nine months ended September 30, 2013 are as follows (in thousands):

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Total
Balance at July 1, 2013 (a)	$	(12,958	)	$	(607	)	$	(3	)	$	(13,568	)
Other comprehensive income before reclassifications	—			—			221			221
Amounts reclassified from AOCL (b)	—			7			—			7
Net current period other comprehensive income (loss)	—			7			221			228
Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Total
Balance at January 1, 2013 (a)	$	(12,958	)	$	(621	)	$	294		$	(13,285	)
Other comprehensive income before reclassifications	—			—			413			413
Amounts reclassified from AOCL (b)	—			21			(489		)	(468		)
Net current period other comprehensive income (loss)	—			21			(76		)	(55		)
Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)

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

(b) See table below.

Reclassifications out of AOCL

The reclassifications out of AOCL and into earnings during the three and nine months ended September 30, 2013 is as follows (in thousands):

Components of AOCL	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Statements of Income
	Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		$	36		Interest Charges
Unrealized Gain on Available-for-Sale Securities	—			(828		)	Other Income & Expense
	12			(792		)	Loss (Income) Before Income Taxes
Income Taxes (a)	(5		)	324			Income Taxes (a)
Losses (Gains) from reclassifications for the period net of tax	$	7		$	(468	)

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

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES, LEVEL THREE INPUTS (Details) (Forward Contracts [Member], Level 3 [Member], Natural Gas (in MMdts) [Member], USD $) In Thousands, unless otherwise specified	Sep. 30, 2013
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Assets	$ 0
Liabilities	$ 319
Minimum [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	(1.75)
Maximum [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	(1.75)
Weighted Average [Member]
Fair Value Inputs, Assets And Liabilities, Quantitative Information [Line Items]
Forward price (in dollars per dt)	(1.75)

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FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES

9 Months Ended

Sep. 30, 2013

Fair Value Disclosures [Abstract]

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES

FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES:

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

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

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

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

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

For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands):

As of September 30, 2013
	Total		Level 1		Level 2		Level 3
Assets -
Available-for-Sale Securities (A)	$	8,237	$	8,237	$	—	$	—
Derivatives – Energy Related Assets (B)	306		306		—		—
	$	8,543	$	8,543	$	—	$	—
Liabilities -
Derivatives – Energy Related Liabilities (B)	$	1,785	$	1,466	$	—	$	319
Derivatives – Other (C)	4,569		—		4,569		—
	$	6,354	$	1,466	$	4,569	$	319

As of December 31, 2012
	Total		Level 1		Level 2		Level 3
Assets
Available-for-Sale Securities (A)	$	7,520	$	769	$	6,751	$	—
Derivatives - Energy Related Assets (B)	766		447		319		—
	$	8,286	$	1,216	$	7,070	$	—
Liabilities
Derivatives - Energy Related Liabilities (B)	$	2,695	$	2,694	$	1	$	—
Derivatives - Other (C)	7,761		—		7,761		—
	$	10,456	$	2,694	$	7,762	$	—

(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 consisted of funds that are not publicly traded.  These funds, which consisted 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. 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. 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. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.

Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

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

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

Type	Fair Value at September 30, 2013		Valuation Technique	Significant Unobservable Input	Range [Weighted Average]
	Assets	Liabilities
Forward Contract - Natural Gas	$—	$319	Discounted Cash Flow	Forward price (per dt)	$(1.75) - $(1.75) [$(1.75)]

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

	Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
Balance at beginning of period	$	(243	)	$	—
Total losses unrealized in Regulatory Liabilities (see note 4)	(76		)	(319		)
Settlements	—			—
	(76		)	(319		)
Balance at September 30	$	(319	)	$	(319	)

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FINANCIAL INSTRUMENTS

9 Months Ended

Sep. 30, 2013

Financial Instruments, Owned, at Fair Value [Abstract]

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS:

RESTRICTED INVESTMENTS - In accordance with the terms of our tax-exempt first mortgage bonds, unused proceeds are required to be escrowed pending approved construction expenditures. As of both September 30, 2013 and December 31, 2012, the escrowed proceeds, including interest earned, totaled $0.1 million. SJG established a margin account with SJRG in conjunction with SJG's risk management activities as detailed in Note 11. The funds provided by SJG will increase or decrease as the number and value of outstanding energy-related contracts held with SJRG changes. As of September 30, 2013 and December 31, 2012, the balance held with SJRG totaled $0.9 million and $1.1 million, respectively. During March 2013, SJG established a margin account with a counterparty in conjunction with SJG's risk management activities as detailed in Note 11. The funds provided by SJG will increase or decrease as the number and value of outstanding energy-related contracts held with this counterparty changes. As of September 30, 2013 the balance held with this counterparty totaled $1.0 million. The carrying amounts of the Restricted Investments approximate their fair value at September 30, 2013 and December 31, 2012, which would be included in Level 1 of the fair value hierarchy. (See Note 10 - Fair Value of Financial Assets and Financial Liabilities).

LONG-TERM RECEIVABLES– SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources.  The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest.  The carrying amounts of such loans were $14.0 million and $13.6 million as of September 30, 2013 and December 31, 2012, respectively.  The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Long-Term Receivables on the condensed balance sheets.  The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.3 million as of both September 30, 2013 and December 31, 2012.  The annual amortization to interest is not material to SJG’s financial statements.  The carrying amounts of these receivables approximate their fair value at September 30, 2013 and December 31, 2012, which would be included in Level 2 of the fair value hierarchy. (See Note 10 - Fair Value of Financial Assets and Financial Liabilities).

FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJG's financial instruments approximate their fair values at September 30, 2013 and December 31, 2012, except as noted below.

• For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to SJG at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy. See Note 10 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJG's long-term debt, including current maturities, as of September 30, 2013 and December 31, 2012, were $446.2 million and $502.0 million, respectively.  The carrying amount of SJG's long-term debt, including current maturities, as of September 30, 2013 and December 31, 2012 was $425.0 million and $450.0 million respectively.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

9 Months Ended

Sep. 30, 2013

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

THE ENTITY - South Jersey Industries, Inc. (SJI) owns all of the outstanding common stock of South Jersey Gas Company (SJG), a regulated natural gas utility. SJG distributes natural gas in the seven southern most counties of New Jersey. In our opinion, the condensed financial statements reflect all normal and recurring adjustments needed to fairly present our financial position and operating results at the dates and for the periods presented. SJG’s business is 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, the accompanying condensed financial statements contain certain condensed financial information and exclude certain note disclosures normally included in annual audited financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These condensed financial statements should be read in conjunction with SJG’s 2012 Form 10-K for a more complete discussion of our accounting policies and certain other information.

REVENUE AND THROUGHPUT - BASED TAXES - SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both revenues and cost of sales, and totaled $0.5 million and $0.7 million for the three months ended September 30, 2013 and 2012, and $3.4 million and $4.0 million for the nine months ended September 30, 2013 and 2012, respectively. The TEFA is subject to a planned phase-out which decreased the assessment in increments of 25% in 2012 and 2013 and is eliminated after December 31, 2013.

NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2012 and 2013 had, or is expected to have, a material impact on the condensed financial statements.

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

In February 2013, in response to ASU 2011-12 discussed above, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.

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

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LONG-TERM DEBT (Details) (Medium-term Notes [Member], USD $)	1 Months Ended			3 Months Ended
	Sep. 30, 2013	Feb. 28, 2012 Series Due 2027, 7.7 Percent [Member]	Apr. 30, 2012 Series Due 2032, 3.74 Percent [Member]	Sep. 30, 2013 Series Due 2013, 4.46 Percent [Member]	Sep. 30, 2013 Series Due 2013, 5.027 Percent [Member]	Sep. 30, 2013 Series Due 2030, 4.01 Percent [Member]	Sep. 30, 2013 Series Due 2030, 4.23 Percent [Member]
Debt Instrument [Line Items]
Debt called		$ 35,000,000.0		$ 10,500,000.0	$ 14,500,000.0
Stated interest rate		7.70%	3.74%	4.46%	5.027%	4.00%	4.20%
Premium in addition to par for called debt		2.00%
Debt issued			35,000,000			50,000,000.0	30,000,000.0
Debt planned for future issuance	$ 80,000,000.0

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RATES AND REGULATORY ACTIONS (Details) (USD $) In Millions, unless otherwise specified	1 Months Ended
	Sep. 30, 2013	Jun. 30, 2013	May 31, 2013	Feb. 28, 2013	Jan. 31, 2013	Oct. 31, 2012	Jul. 31, 2012
Public Utilities, General Disclosures [Abstract]
Cost requested to be recovered through EEP I, approved additional investment					$ 2.5
Cost requested to be recovered through EEP, revenue increase		24.0
BGSS refunds made to customers					9.4
Investment requested to be recovered through CIRT III, term of AIRP				4 years			5 years
Investment requested to be recovered through CIRT III, amount of AIRP				141.2			250.0
Investment requested to be recovered through CIRT III, annual amount of AIRP				35.3			50.0
Petition to adjust BGSS and CIP, revenue decrease			17.9
Investment requested to be recovered through CIRT, revenue increase			15.5			13.2
Investment requested to be recovered through CIRT, investments to be rolled into base rate			6.9			110.6
CIRT investments						117.5
Costs requested for deferral, storm related		0.7
Investment requested to be recovered through SHARP	$ 280.0
Investment requested to be recovered through SHARP, term	7 years

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ACCUMULATED OTHER COMPREHENSIVE LOSS

9 Months Ended

Sep. 30, 2013

Equity [Abstract]

ACCUMULATED OTHER COMPREHENSIVE LOSS

ACCUMULATED OTHER COMPREHENSIVE LOSS:

The changes in Accumulated Other Comprehensive Loss (AOCL) for the three and nine months ended September 30, 2013 are as follows (in thousands):

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Total
Balance at July 1, 2013 (a)	$	(12,958	)	$	(607	)	$	(3	)	$	(13,568	)
Other comprehensive income before reclassifications	—			—			221			221
Amounts reclassified from AOCL (b)	—			7			—			7
Net current period other comprehensive income (loss)	—			7			221			228
Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)

	Postretirement Liability Adjustment			Unrealized Gain (Loss) on Derivatives-Other			Unrealized Gain (Loss) on Available-for-Sale Securities			Total
Balance at January 1, 2013 (a)	$	(12,958	)	$	(621	)	$	294		$	(13,285	)
Other comprehensive income before reclassifications	—			—			413			413
Amounts reclassified from AOCL (b)	—			21			(489		)	(468		)
Net current period other comprehensive income (loss)	—			21			(76		)	(55		)
Balance at September 30, 2013 (a)	$	(12,958	)	$	(600	)	$	218		$	(13,340	)

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

(b) See table below.

The reclassifications out of AOCL and into earnings during the three and nine months ended September 30, 2013 is as follows (in thousands):

Components of AOCL	Amounts Reclassified from AOCL (in thousands)						Affected Line Item in the Condensed Statements of Income
	Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
Unrealized Loss on Derivatives-Other - Interest Rate Contracts designated as cash flow hedges	$	12		$	36		Interest Charges
Unrealized Gain on Available-for-Sale Securities	—			(828		)	Other Income & Expense
	12			(792		)	Loss (Income) Before Income Taxes
Income Taxes (a)	(5		)	324			Income Taxes (a)
Losses (Gains) from reclassifications for the period net of tax	$	7		$	(468	)

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

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COMMITMENTS AND CONTINGENCIES

9 Months Ended

Sep. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES:

STANDBY LETTER OF CREDIT -    SJG provided a $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 New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system. 

ENVIRONMENTAL REMEDIATION COSTS - SJG 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. There have been no significant changes to the status of SJG’s environmental remediation efforts since December 31, 2012, as described in Note 12 to the Financial Statements in Item 8 of SJG’s Form 10-K as of December 31, 2012.

GAS SUPPLY RELATED CONTRACTS - In the normal course of conducting business, we have entered into long-term contracts for natural gas supplies, firm transportation and gas storage service. The earliest date at which any of the primary terms of these contracts expire is October 2014. The transportation and storage agreements entered into between us and each of our interstate pipeline service providers were done so in accordance with their respective FERC approved tariff. Our cumulative obligation for gas supply related demand charges and reservation fees paid for these services averages approximately $4.3 million per month and is recovered on a current basis through the BGSS.

PENDING LITIGATION - We are subject to claims arising in the ordinary course of business and other legal proceedings. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $0.4 million and $0.5 million related to all claims in the aggregate, as of September 30, 2013 and December 31, 2012, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.

COLLECTIVE BARGAINING AGREEMENTS - Unionized personnel represent approximately 60% of our workforce at September 30, 2013. The Company has collective bargaining agreements with two unions who represent these employees: the International Brotherhood of Electrical Workers (IBEW) operates under a collective bargaining agreement that runs through February 28, 2017, and the International Association of Machinists and Aerospace Workers (IAM) operates under a collective bargaining agreement that expires in August 2014.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

9 Months Ended

Sep. 30, 2013

Accounting Policies [Abstract]

REVENUE BASED TAXES

REVENUE AND THROUGHPUT - BASED TAXES - SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both revenues and cost of sales, and totaled $0.5 million and $0.7 million for the three months ended September 30, 2013 and 2012, and $3.4 million and $4.0 million for the nine months ended September 30, 2013 and 2012, respectively. The TEFA is subject to a planned phase-out which decreased the assessment in increments of 25% in 2012 and 2013 and is eliminated after December 31, 2013.

NEW ACCOUNTING PRONOUNCEMENTS

NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2012 and 2013 had, or is expected to have, a material impact on the condensed financial statements.

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

In February 2013, in response to ASU 2011-12 discussed above, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.

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

FAIR VALUE

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 consisted of funds that are not publicly traded.  These funds, which consisted 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. 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. 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. Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value.

Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical forwards, which calculates mark-to-market valuations based on forward prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts are forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.

(C)  Derivatives – Other, include interest rate swaps that 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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EQUITY CONTRIBUTIONS

9 Months Ended

Sep. 30, 2013

Equity [Abstract]

EQUITY CONTRIBUTIONS

EQUITY CONTRIBUTION:

We received an equity infusion of $25.0 million from SJI during September 2013. Contributions of capital are credited to Other Paid-In Capital and Premium on Common Stock. Further equity contributions will occur on an as needed basis.

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DOCUMENT AND ENTITY INFORMATION Document	9 Months Ended
	Sep. 30, 2013	Nov. 01, 2013
Document and Entity Information [Abstract]
Entity Registrant Name	SOUTH JERSEY GAS Co
Entity Central Index Key	0001035216
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		2,339,139

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SUBSEQUENT EVENT

9 Months Ended

Sep. 30, 2013

Subsequent Events [Abstract]

SUBSEQUENT EVENT

SUBSEQUENT EVENT:

In October 2013, SJG filed a petition with the New Jersey Board of Public Utilities to issue up to $200.0 million of long term debt securities in various forms including Medium Term Notes and unsecured debt, with maturities of more than 12 months, over the next three years. This petition is currently pending.