Edgar Filing: NEW JERSEY RESOURCES CORP

form10qa.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q/A

Amendment No. 1

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

FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2009

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 001-8359

NEW JERSEY RESOURCES CORPORATION

(Exact name of registrant as specified in its charter)

New Jersey		22-2376465
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

1415 Wyckoff Road, Wall, New Jersey 07719		732-938-1480
(Address of principal executive offices)		(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12 (b) of the Act:
Common Stock - $2.50 Par Value		New York Stock Exchange
(Title of each class)		(Name of each exchange on which registered)

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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes: o No: o

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

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

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

The number of shares outstanding of $2.50 par value Common Stock as of August 4, 2009, was 42,014,773.

EXPLANATORY NOTE

Overview

New Jersey Resources Corporation (the “Company”) is filing this Amendment No. 1 on Form 10-Q/A to our quarterly report on Form 10-Q for the quarter ended June 30, 2009, originally filed on August 5, 2009, to amend and restate our unaudited condensed consolidated financial statements for the three and nine month periods ended June 30, 2009 and 2008 and for the condensed consolidated balance sheets as of June 30, 2009 and September 30, 2008 to correct an error related to the accounting for park and loan transactions executed through the Company’s unregulated subsidiary, NJR Energy Services (NJRES).

Restatement

NJRES enters into park and loan transactions whereby it borrows natural gas from a counterparty with an obligation to return the gas at a future date. In the fourth quarter of fiscal 2009, management discovered an error in the accounting for gas in storage, purchase obligations, embedded derivatives and gas demand fees associated with these transactions. Specifically, NJR had been using a forward price to value the inventory and gas purchases liability. Both the natural gas that was received and the “park and loan” liability should have been initially valued at the spot price on the date NJRES received the gas. In addition, NJRES should have been accounting for the obligation to return the gas as an embedded derivative, which should have been fair valued (“marked to market”) at each subsequent balance sheet reporting date until the gas was returned to the counterparty. As well, the initial spread between the spot price of the borrowed gas liability on the date of the transaction and the forward price, based on the date NJRES would return the natural gas, should have been recognized into income on a ratable basis over the term of the park and loan agreement. In addition, demand fees related to these transactions were not but should have been recognized ratably over the term of the contract.

These errors, while impacting our reported results in accordance with generally accepted accounting principles (“GAAP”), have no impact on our Non-GAAP measure of Net Financial Earnings (“NFE”), which excludes the impact of unrealized derivative gains and losses, effects of economic hedging related to inventory and demand fees related to park and loan transactions. As discussed in the MD&A, NFE is the key financial metric by which we measure the profitability of the Company.

The Company is also filing amended Quarterly Reports on Form 10-Q/A for the quarters ended, December 31, 2008 and March 31, 2009 to correct the errors described above.

The Company originally filed its Form 10-Q with the Securities and Exchange Commission on August 5, 2009, and therefore, had initially evaluated subsequent events through that date. All of the information in this Form 10-Q/A is as of November 24 2009 and management has determined that there are no other subsequent events to be reported other than the restatement discussed in Note 2 to the Consolidated Financial Statements appearing in this Form 10-Q/A. For the convenience of the reader, this Form 10-Q/A sets forth the originally filed Form 10-Q in its entirety. However, the following items have been amended solely as a result of, and to reflect, the restatement, and no other information in the Form 10-Q/A is amended hereby as a result of the restatement:

Part I, Item 1 - Financial Statements

Part I, Item 2 - Management’s Discussion and Analysis of Financial Condition and Results of Operations

Part I, Item 4 - Controls and Procedures

Part II — Item 6. Exhibits.

In the Quarterly Reports on Form 10-Q as previously filed, the Company reported under Item 4 “Controls and Procedures,” that its disclosure controls and procedures were not effective due to a material weakness in internal control over financial reporting. Management, in consultation with the Audit Committee, has concluded that the errors set forth herein constituted a material weakness in the Company’s internal controls over financial reporting as of the date of the original filing, which has since been remediated. The revised assessment is included under Part II, Item 4 in this document.

The Company is including currently dated Sarbanes-Oxley Act Section 302 and Section 906 certifications of the Chief Executive Officer and Chief Financial Officer that are attached to this Form 10-Q/A as Exhibits 31.1, 31.2, 32.1 and 32.2.

This Form 10-Q/A amends or updates any other information set forth in the Form 10-Q including updated disclosures contained therein as applicable to reflect any events that occurred at a date subsequent to the filing of the originally filed Form 10-Q. Accordingly, this Form 10-Q/A should be read in conjunction with our filings made with the Securities and Exchange Commission subsequent to the filing of the original Form 10-Q, including any amendments to those filings.

New Jersey Resources Corporation

TABLE OF CONTENTS

			Page
Information Concerning Forward-Looking Statements			1

PART I – FINANCIAL INFORMATION
ITEM 1.	Unaudited Condensed Consolidated Financial Statements (Restated)		2
	Notes to Unaudited Condensed Consolidated Financial Statements		7
	Note 1	General	7
	Note 2	Restatement Of Unaudited Condensed Consolidated Financial Statements	9
	Note 3	Regulation	12
	Note 4	Derivative Instruments	16
	Note 5	Fair Value	19
	Note 6	Investments In Equity Investees	20
	Note 7	Earnings Per Share	21
	Note 8	Debt	21
	Note 9	Capitalized Financing Costs And Deferred Interest	23
	Note 10	Stock-Based Compensation	24
	Note 11	Employee Benefit Plans	24
	Note 12	Asset Retirement Obligations	25
	Note 13	Income Taxes	25
	Note 14	Commitments And Contingent Liabilities	25
	Note 15	Business Segment and Other Operations Data	28
	Note 16	Related Party Transactions	30
	Note 17	Other	30
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations for the Three and Nine Months Ended June 30, 2009		30
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk		53
ITEM 4.	Controls and Procedures		56

PART II – OTHER INFORMATION
ITEM 1.	Legal Proceedings		58
ITEM 1A.	Risk Factors		58
ITEM 2.	Unregistered Sale of Equity Securities and Use of Proceeds		58
ITEM 6.	Exhibits		59
	Signatures		60

Table of Contents

New Jersey Resources Corporation

Part I

INFORMATION CONCERNING FORWARD-LOOKING STATEMENTS

Certain statements contained in this report, including, without limitation, statements as to management expectations and beliefs presented in Part I, Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” Part I, Item 3. “Quantitative and Qualitative Disclosures about Market Risk,” Part II, Item I. “Legal Proceedings” and in the notes to the financial statements are forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements can also be identified by the use of forward-looking terminology such as “may,” “intend,” “expect,” “believe” or “continue” or comparable terminology and are made based upon management’s expectations and beliefs concerning future developments and their potential effect upon New Jersey Resources Corporation (NJR or the Company). There can be no assurance that future developments will be in accordance with management’s expectations or that the effect of future developments on the Company will be those anticipated by management.

The Company cautions readers that the assumptions that form the basis for forward-looking statements regarding customer growth, customer usage, financial condition, results of operations, cash flows, capital requirements, market risk and other matters for fiscal 2009 and thereafter include many factors that are beyond the Company’s ability to control or estimate precisely, such as estimates of future market conditions, the behavior of other market participants and changes in the debt and equity capital markets. The factors that could cause actual results to differ materially from NJR’s expectations include, but are not limited to, those discussed in Risk Factors in Part II, Item 1A, as well as the following:

Ÿ	weather and economic conditions;

Ÿ	demographic changes in the New Jersey Natural Gas (NJNG) service territory;

Ÿ	the rate of NJNG customer growth;

Ÿ	volatility of natural gas commodity prices and its impact on customer usage, cash flow, NJR Energy Services’ (NJRES) operations and on the Company’s risk management efforts;

Ÿ	changes in rating agency requirements and/or credit ratings and their effect on availability and cost of capital to the Company;

continued volatility or seizure of the credit markets that would result in the decreased availability and access to credit at NJR to fund and support physical gas inventory purchases and other working capital needs at NJRES, and all other non-regulated subsidiaries, as well as negatively affect access to the commercial paper market and other short-term financing markets at NJNG to allow it to fund its commodity purchases and meet its short-term obligations as they come due;

Ÿ	the impact to the asset values and resulting higher costs and funding obligations of NJR’s pension and postemployment benefit plans as a result of declines in the financial markets;

Ÿ	increases in borrowing costs associated with variable-rate debt;

Ÿ	commercial and wholesale credit risks, including creditworthiness of customers and counterparties;

Ÿ	the ability to obtain governmental approvals and/or financing for the construction, development and operation of certain non-regulated energy investments;

Ÿ	risks associated with the management of the Company’s joint ventures and partnerships;

Ÿ	the impact of governmental regulation (including the regulation of rates);

Ÿ	conversion activity and other marketing efforts;

Ÿ	actual energy usage of NJNG’s customers;

Ÿ	the pace of deregulation of retail gas markets;

Ÿ	access to adequate supplies of natural gas;

Ÿ	the regulatory and pricing policies of federal and state regulatory agencies;

Ÿ	the ultimate outcome of pending regulatory proceedings, including the possible expiration of the Conservation Incentive Program (CIP);

Ÿ	changes due to legislation at the federal and state level;

Ÿ	the availability of an adequate number of appropriate counterparties in the wholesale energy trading market;

Ÿ	sufficient liquidity in the wholesale energy trading market and continued access to the capital markets;

Ÿ	the disallowance of recovery of environmental-related expenditures and other regulatory changes;

Ÿ	environmental-related and other litigation and other uncertainties;

Ÿ	the effects and impacts of inflation on NJR and its subsidiaries operations;

Ÿ	change in accounting pronouncements issued by the appropriate standard setting bodies; and

Ÿ	terrorist attacks or threatened attacks on energy facilities or unrelated energy companies.

While the Company periodically reassesses material trends and uncertainties affecting the Company’s results of operations and financial condition in connection with its preparation of management’s discussion and analysis of results of operations and financial condition contained in its Quarterly and Annual Reports, the Company does not, by including this statement, assume any obligation to review or revise any particular forward-looking statement referenced herein in light of future events.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited)

	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands, except per share data)	2009			2008			2009		2008
	As Restated (See Note 2)			As Restated (See Note 2)			As Restated (See Note 2)		As Restated (See Note 2)

OPERATING REVENUES	$	441,052		$	1,000,439		$	2,179,872	$	2,989,122

OPERATING EXPENSES
Gas purchases		400,487			974,677			1,859,495		2,716,761
Operation and maintenance		38,436			34,187			112,209		100,971
Regulatory rider expenses		6,280			5,925			40,585		35,879
Depreciation and amortization		7,880			9,680			22,749		28,600
Energy and other taxes		11,739			10,711			67,353		58,245
Total operating expenses		464,822			1,035,180			2,102,391		2,940,456
OPERATING (LOSS) INCOME		(23,770	)		(34,741	)		77,481		48,666
Other income		1,179			237			3,095		3,305
Interest expense, net of capitalized interest		5,187			5,182			15,953		19,684
(LOSS) INCOME BEFORE INCOME TAXES AND EQUITY IN EARNINGS OF AFFILIATES		(27,778	)		(39,686	)		64,623		32,287
Income tax (benefit) provision		(12,146	)		(14,379	)		21,296		11,015
Equity in earnings of affiliates, net of tax		1,477			378			2,778		1,548
NET (LOSS) INCOME	$	(14,155	)	$	(24,929	)	$	46,105	$	22,820

(LOSS) EARNINGS PER COMMON SHARE
BASIC	$	(0.34	)	$	(0.59	)	$	1.09	$	0.55
DILUTED	$	(0.34	)	$	(0.59	)	$	1.08	$	0.54

DIVIDENDS PER COMMON SHARE	$	0.31		$	0.28		$	0.93	$	0.83

WEIGHTED AVERAGE SHARES OUTSTANDING
BASIC		42,049			41,949			42,175		41,822
DILUTED		42,049			41,949			42,547		42,037

See Notes to Unaudited Condensed Consolidated Financial Statements

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	Nine Months Ended June 30,
(Thousands)	2009			2008
	As Restated (See Note 2)			As Restated (See Note 2)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	46,105		$	22,820
Adjustments to reconcile net income to cash flows from operating activities:
Unrealized loss on derivative instruments		65,160			84,498
Depreciation and amortization		23,417			29,369
Allowance for funds (equity) used during construction		(233	)		—
Allowance for bad debt expense		5,015			3,104
Deferred income taxes		12,732			(10	)
Manufactured gas plant remediation costs		(12,280	)		(13,263	)
Equity in earnings from investments, net of distributions		3,858			388
Cost of removal – asset retirement obligations		(508	)		(888	)
Contributions to employee benefit plans		(1,768	)		(521	)
Changes in:
Components of working capital		243,048			(25,561	)
Other noncurrent assets		(23,611	)		17,596
Other noncurrent liabilities		(10,251	)		26,763
Cash flows from operating activities		350,684			144,295
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for:
Utility plant		(51,169	)		(51,472	)
Real estate properties and other		(356	)		(888	)
Cost of removal		(4,014	)		(5,775	)
Investments in equity investees		(41,343	)		(16,595	)
Release from restricted cash construction fund		4,200			—
Cash flows used in investing activities		(92,682	)		(74,730	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of common stock		13,327			13,072
Proceeds from long-term debt		—			125,000
Tax benefit from stock options exercised		993			677
Proceeds from sale-leaseback transaction		6,268			7,485
Payments of long-term debt		(58,860	)		(3,977	)
Purchases of treasury stock		(17,757	)		(11,040	)
Payments of common stock dividends		(37,977	)		(33,451	)
Net payments from short-term debt		(129,600	)		(146,579	)
Cash flows used in financing activities		(223,606	)		(48,813	)
Change in cash and temporary investments		34,396			20,752
Cash and temporary investments at beginning of period		42,626			5,140
Cash and temporary investments at end of period	$	77,022		$	25,892
CHANGES IN COMPONENTS OF WORKING CAPITAL
Receivables	$	97,642		$	(214,552	)
Inventories		260,883			37,233,
Recovery of gas costs		58,836			(18,037	)
Gas purchases payable		(144,528	)		246,495
Prepaid and accrued taxes		37,792			21,075
Accounts payable and other		2,271			(8,871	)
Restricted broker margin accounts		(27,814	)		(73,016	)
Customers’ credit balances and deposits		(43,162	)		(11,632	)
Other current assets		1,128			(4,256	)
Total	$	243,048		$	(25,561	)
SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION
Cash paid for:
Interest (net of amounts capitalized)	$	13,498		$	17,972
Income taxes	$	12,685		$	25,477

See Notes to Unaudited Condensed Consolidated Financial Statements

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

ASSETS

	June 30,			September 30,
(Thousands)	2009			2008
	As Restated (See Note 2)			As Restated (See Note 2)
PROPERTY, PLANT AND EQUIPMENT
Utility plant, at cost	$	1,418,320		$	1,366,237
Real estate properties and other, at cost		30,163			29,808
		1,448,483			1,396,045
Accumulated depreciation and amortization		(399,005	)		(378,759	)
Property, plant and equipment, net		1,049,478			1,017,286

CURRENT ASSETS
Cash and temporary investments		77,022			42,626
Customer accounts receivable
Billed		126,128			227,132
Unbilled revenues		9,739			9,417
Allowance for doubtful accounts		(6,555	)		(4,580	)
Regulatory assets		6,318			51,376
Gas in storage, at average cost		206,413			467,537
Materials and supplies, at average cost		5,351			5,110
Prepaid state taxes		35,660			37,271
Derivatives, at fair value		164,560			227,224
Restricted broker margin accounts		49,204			41,277
Deferred taxes		17,882			—
Other		30,990			15,181
Total current assets		722,712			1,119,571

NONCURRENT ASSETS
Investments in equity investees		156,311			115,981
Regulatory assets		359,876			340,670
Derivatives, at fair value		13,345			24,497
Restricted cash construction fund		—			4,200
Other		11,577			13,092
Total noncurrent assets		541,109			498,440
Total assets	$	2,313,299		$	2,635,297

See Notes to Unaudited Condensed Consolidated Financial Statements

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

CAPITALIZATION AND LIABILITIES

	June 30,		September 30,
(Thousands)	2009		2008
	As Restated (See Note 2)		As Restated (See Note 2)
CAPITALIZATION
Common stock equity	$	735,496	$	728,068
Long-term debt		457,671		455,117
Total capitalization		1,193,167		1,183,185

CURRENT LIABILITIES
Current maturities of long-term debt		5,995		60,119
Short-term debt		48,600		178,200
Gas purchases payable		179,072		323,600
Accounts payable and other		49,229		61,735
Dividends payable		13,004		11,776
Deferred and accrued taxes		47,088		24,720
Regulatory liabilities		30,842		—
New Jersey clean energy program		10,805		3,056
Derivatives, at fair value		151,365		146,320
Restricted broker margin accounts		9,185		29,072
Customers’ credit balances and deposits		20,294		63,455
Total current liabilities		565,479		902,053

NONCURRENT LIABILITIES
Deferred income taxes		233,598		240,414
Deferred investment tax credits		6,951		7,192
Deferred revenue		7,828		9,090
Derivatives, at fair value		9,000		25,016
Manufactured gas plant remediation		120,230		120,730
Postemployment employee benefit liability		55,795		52,272
Regulatory liabilities		58,634		63,419
New Jersey clean energy program		29,155		—
Asset retirement obligation		25,021		24,416
Other		8,441		7,510
Total noncurrent liabilities		554,653		550,059
Commitments and contingent liabilities (Note 14)
Total capitalization and liabilities	$	2,313,299	$	2,635,297

See Notes to Unaudited Condensed Consolidated Financial Statements

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 1. FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2009			2008			2009			2008
	As Restated (See Note 2)			As Restated (See Note 2)			As Restated (See Note 2)			As Restated (See Note 2)

Net (loss) income	$	(14,155	)	$	(24,929	)	$	46,105		$	22,820
Other comprehensive (loss) income
Unrealized (loss) gain on available for sale securities, net of tax of $10, $(206), $74 and $(235), respectively (1)		(14	)		296			(106	)		336
Net unrealized (loss) on derivatives, net of tax of $16, $3, $50 and $64, respectively		(23	)		(42	)		(71	)		(92	)
Other comprehensive income		(37	)		254			(177	)		244
Comprehensive income	$	(14,192	)	$	(24,675	)	$	45,928		$	23,064

(1)

Available for sale securities are included in Investments in equity investees in the Unaudited Condensed Consolidated Balance Sheets.

See Notes to Unaudited Condensed Consolidated Financial Statements

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New Jersey Resources Corporation

Part I

NOTES TO CONDENSED UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

GENERAL

The accompanying unaudited condensed consolidated financial statements have been prepared by New Jersey Resources Corporation (NJR or the Company) in accordance with the rules and regulations of the Securities and Exchange Commission (SEC). The September 30, 2008 balance sheet data is derived from the audited financial statements of the Company. These unaudited condensed consolidated financial statements should be read in conjunction with the financial statements and the notes thereto included in NJR’s 2008 Annual Report on Form 10-K.

The unaudited condensed consolidated financial statements include the accounts of NJR and its subsidiaries, New Jersey Natural Gas Company (NJNG), NJR Energy Services Company (NJRES), NJR Retail Holdings Corporation (Retail Holdings), NJR Energy Investment Corporation (NJREI) and NJR Service Company (NJR Service). Intercompany transactions and accounts have been eliminated. NJREI’s primary subsidiaries are NJR Energy Corporation (NJR Energy) and NJR Steckman Ridge Storage Company. NJR Energy invests primarily in energy-related ventures through its subsidiary, NJNR Pipeline Company (Pipeline), which holds the Company’s 5.53 percent ownership interest in Iroquois Gas and Transmission System, L.P. (Iroquois). NJR Steckman Ridge Storage Company holds the Company’s 50 percent combined interest in Steckman Ridge GP, LLC and Steckman Ridge, LP (collectively, Steckman Ridge), a natural gas storage facility that was acquired and is being developed with a partner in Pennsylvania. Retail Holdings’ two principal subsidiaries are NJR Home Services Company (NJRHS) and Commercial Realty & Resources Corporation (CR&R).

In the opinion of management, the accompanying unaudited condensed consolidated financial statements reflect all adjustments necessary, for a fair presentation of the results of the interim periods presented. These adjustments are of a normal and recurring nature. Because of the seasonal nature of NJR’s utility and wholesale energy services operations, in addition to other factors, the financial results for the interim periods presented are not indicative of the results that are to be expected for the fiscal year ended September 30, 2009.

Subsequent Events

The Company evaluates subsequent events through the date it issues its financial statements. Accordingly, for the period ended June 30, 2009, events occurring between June 30, 2009 and November 24, 2009, have been reviewed to determine appropriate recognition and disclosures. See Note 3, Regulation, for subsequent events disclosures.

Customer Accounts Receivable

Customer accounts receivable include outstanding billings from the following subsidiaries as of:

	June 30,				September 30,
(Thousands)	2009				2008
NJNG	$	11,211	9	%	$	21,398	9	%
NJRES		106,431	84			198,902	88
NJRHS and other		8,486	7			6,832	3
Total	$	126,128	100	%	$	227,132	100	%

Accounts receivable decreased during the nine months ended June 30, 2009, due primarily to the impact of lower commodity prices on NJRES’ receivables.

Gas in Storage

The following table summarizes Gas in storage by company as of:

	June 30,				September 30,
	2009				2008
($ in thousands)	Assets		Bcf		Assets		Bcf
NJNG	$	113,480		14.2	$	189,828		22.1
NJRES		92,933		28.1		277,709		27.6
Total	$	206,413		42.3	$	467,537		49.7

Gas in storage decreased during the nine months ended June 30, 2009, due primarily to the seasonal reduction in volumes at NJNG and lower cost of inventory purchases at NJRES stemming from a decline in commodity prices.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

New Accounting Standards

Recently Adopted

On April 10, 2007, the FASB issued FASB Staff Position (FSP) No. FIN 39-1 (FSP FIN 39-1), Amendment of FASB Interpretation No. 39. FSP FIN 39-1 provides additional guidance for parties that are subject to master netting arrangements. Specifically, for transactions that are executed with the same counterparty, it permits companies to offset the fair values of amounts recognized for derivatives as well as the related fair value amounts of cash collateral receivables or payables, when certain conditions apply. FSP FIN 39-1 became effective for fiscal years beginning after November 15, 2007. As NJR’s policy has been to present its derivative positions and any receivables or payables with the same counterparty on a gross basis, FSP FIN 39-1 had no impact on its statement of financial position or results of operations.

Effective October 1, 2008 NJR adopted Statement of Financial Accounting Standards (SFAS) No. 157, Fair Value Measurements (SFAS 157) for its financial assets and liabilities, with the exception of its pension assets. On October, 1, 2009, in accordance with SFAS 157-2, NJR will prospectively apply the provisions of SFAS 157 to its non-financial assets and liabilities that are not measured at least annually. In addition, the provisions of SFAS 157 will be applied to NJR’s annual pension disclosures in accordance with FASB Staff Position (FSP) No. FAS 132(R)-1 (FSP 132(R)-1), Employers’ Disclosures about Pensions and Other Postretirement Benefits, beginning in fiscal 2010.

SFAS 157 defines fair value as the amount that would be exchanged to sell an asset or transfer a liability in an orderly transaction between market participants, and establishes a fair value hierarchy of market and unobservable data that is used to develop pricing assumptions. The adoption of SFAS 157 did not have a material impact on NJR’s financial position or results of operations. See Note 5, Fair Value, for more information on the adoption of SFAS 157, as well as the required disclosures.

In March 2008, the FASB issued SFAS No. 161, Disclosures about Derivative Instruments and Hedging Activities, (SFAS 161). SFAS 161 requires enhanced qualitative and quantitative disclosures on the objectives and accounting for derivatives and related hedging activities, as well as their impacts on the financial statements. NJR adopted SFAS 161 effective January 1, 2009. As SFAS 161 provisions only require additional disclosures, there was no impact to NJR’s statement of financial position or results of operations upon adoption. See Note 4 Derivative Instruments for a description of NJR’s derivative activities, including the additional disclosures required by SFAS 161.

On April 9, 2009, the FASB issued FSP No. FAS 107-1 and APB 28-1, Interim Disclosures about Fair Values of Financial Instruments, which amends SFAS 107, Disclosures about Fair Values of Financial Instruments, and requires that companies also disclose the fair value of financial instruments during interim reporting similar to those that are currently provided annually. NJR adopted the provisions of FSP No. FAS 107-1 and APB 28-1 effective June 30, 2009. As it is a disclosure only standard, it had no impact on the Company’s statement of financial position or results of operations. See Note 5, Fair Value, for more information on the required disclosures.

In April 2009, the FASB issued FSP FAS 157-4 Determining Fair Value When the Volume and Level of Activity for the Asset or Liability Have Significantly Decreased and Identifying Transactions That Are Not Orderly. The FSP provides additional guidance for estimating fair value in accordance with SFAS 157 when the volume and level of activity for the asset or liability have significantly decreased. In addition, it includes guidance on identifying circumstances that indicate a transaction is not orderly. The FSP became effective for interim and annual reporting periods ending after June 15, 2009. There was no impact to NJR’s statement of financial position or results of operations as a result of the adoption of the FSP.

In April 2009, the FASB issued FSP FAS 115-2 and FAS 124-2 Recognition and Presentation of Other-Than-Temporary Impairments. The FSP improves presentation and disclosures in financial statements for other-than-temporary impairments of debt and equity securities and expands on the factors companies should consider when evaluating debt securities for other-than-temporary impairments. The FSP is effective for interim and annual reporting periods ending after June 15, 2009. There was no impact to NJR’s statement of financial position or results of operations as a result of NJR’s adoption of the FSP.

In May 2009, the FASB issued SFAS 165, Subsequent Events. SFAS 165 establishes general standards of accounting for and disclosure of events that occur after the balance sheet date but before financial statements are issued or are available to be issued, including the date through which financial statements may be reissued. In addition, SFAS 165 includes a new required disclosure of the date through which an entity has evaluated subsequent events. As SFAS 165 is effective for interim or annual periods ending after June 15, 2009, NJR adopted its provisions effective June 30, 2009. There was no impact to NJR’s statement of financial position or results of operations as a result of the adoption.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Other Recently Issued Standards

In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities (SFAS 159). SFAS 159 permits entities to elect to measure eligible items at fair value as an alternative to hedge accounting and to mitigate volatility in earnings. A company can either elect the fair value option according to a pre-existing policy, when the asset or liability is first recognized or when it enters into an eligible firm commitment. Changes in the fair value of assets and liabilities that the company chooses to apply the fair value option to, are reported in earnings at each reporting date. SFAS 159 also provides guidance on disclosures that are intended to provide comparability to other companies’ assets and liabilities that have different measurement attributes and to other companies with similar financial assets and liabilities. SFAS 159 became effective for NJR as of October 1, 2008; however, since the Company did not elect the fair value option for any items, the provisions of SFAS 159 do not impact its statement of financial position or results of operations.

On December 4, 2007, the FASB issued SFAS No. 160, Non-controlling Interests in Consolidated Financial Statements (SFAS 160). SFAS 160 is an amendment of Accounting Research Bulletin (ARB) No. 51 and was issued to improve the relevance, comparability and transparency of the financial information that a reporting entity provides in its consolidated financial statements. This Statement applies to all entities that prepare consolidated financial statements, except not-for-profit organizations, but will affect only those entities that have an outstanding non-controlling interest in one or more subsidiaries. SFAS 160 clarifies that a non-controlling interest in a subsidiary is an ownership interest in the consolidated entity that should be reported as equity in the consolidated financial statements and that a parent company must recognize a gain or loss in net income when a subsidiary is deconsolidated. SFAS 160 is effective for fiscal years beginning after December 15, 2008, and early adoption is prohibited. The Company has concluded that this statement will have no impact on its statement of financial position or results of operations.

On December 30, 2008, the FASB issued FSP 132(R)-1, which requires additional disclosures surrounding postretirement benefit plan assets. Specifically, the objective of FSP 132(R)-1 is to provide users of financial statements information related to a company’s plan assets, investment policies and strategies and significant concentrations of risk. In addition, certain disclosure provisions from FAS 157 will be applied, including those related to inputs and valuation techniques that are used to measure plan assets and the effect of level three measurements on changes in plan assets. FSP 132(R)-1 is effective for fiscal years ending after December 15, 2009. As it is a disclosure only standard, it will have no impact on the Company’s statement of financial position or results of operations.

In June 2009, the FASB issued SFAS No. 167 (SFAS 167), Amendments to FASB Interpretation No. 46 (R) (FIN 46(R)), which will eliminate the quantitative assessments currently in practice under FIN 46 (R), and instead will require qualitative assessments to determine whether a company has a controlling financial interest in a variable interest entity (VIE) and, therefore, would be deemed the primary beneficiary, resulting in consolidation of the VIE’s operating results. In addition, SFAS 167 requires ongoing reassessments, rather than limiting the reassessments to when certain triggering events occur, and additional disclosures that are intended to provide information on a company’s involvement with VIE’s. SFAS 167 is effective at the beginning of a company’s annual reporting period that begins after November 15, 2009, including interim reporting periods within the first annual reporting period, and thereafter. The Company will adopt the provisions of the statement prospectively during its first quarter of fiscal 2011 and is evaluating the effect on its financial position and results of operations.

In June 2009, the FASB issued SFAS No. 168 (SFAS 168), The FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles, as a replacement to SFAS 162. SFAS 168 establishes the FASB Accounting Standards Codification (Codification) as the source of authoritative U.S. generally accepted accounting principles (GAAP) recognized by the FASB to be applied by nongovernmental entities and clarifies that once the Codification takes effect, the GAAP hierarchy will include only two levels of GAAP: authoritative and nonauthoritative. SFAS 168 is effective for financial statements issued for interim and annual periods ending after September 15, 2009. There will be no impact to NJR’s financial statements upon adoption, however, certain disclosures surrounding GAAP guidance will be modified to reflect the appropriate references to the Codification.

2.	RESTATEMENT OF UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NJRES enters into park and loan transactions whereby it borrows natural gas from a counterparty with an obligation to return the gas at a future date. In the fourth quarter of fiscal 2009, management discovered an error in the accounting for gas in storage, purchase obligations, embedded derivatives and gas demand fees associated with these transactions. The impact of the errors was limited to NJRES. Specifically, NJR had been using a forward price to value the inventory and gas purchases liability. Both the natural gas that was received and the “park and loan” liability should have been initially valued at the spot price on the date NJRES received the gas. In addition, NJRES should have been accounting for the obligation to return the gas as an embedded derivative, which should have been fair valued (“marked to market”) at each subsequent balance sheet reporting date until the gas was returned to the counterparty. As well, the initial spread between the spot price of the borrowed gas liability on the date of the transaction and the forward price, based on the date NJRES would return the natural gas, should have been recognized into income on a ratable basis over the term of the park and loan agreement. In addition, demand fees related to these transactions were not but should have been recognized ratably over the term of the contract.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

These errors, while impacting our reported GAAP results, have no impact on our Non-GAAP measure of Net Financial Earnings (“NFE”), which excludes the impact of unrealized derivative gains and losses, effects of economic hedging related to inventory and demand fees related to park and loan transactions. As discussed in the MD&A, NFE is the key financial metric by which we measure the profitability of the Company.

To correct this accounting error, the Company is restating, herein, the unaudited condensed consolidated financial statements for the three and nine months ended June 30, 2009 and 2008 and condensed consolidated balance sheets as of June 30, 2009 and September 30, 2008.

EFFECTS OF RESTATEMENT

The following tables set forth the effects of the restatement on affected line items within the Company’s previously reported financial statements.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited)

	Three Months Ended June 30,									Three Months Ended June 30,
	2009									2008
(Thousands)	As Previously Reported			Adjustment			As Restated			As Previously Reported			Adjustment			As Restated
Gas purchases	$	400,783		$	(296	)	$	400,487		$	945,629		$	29,048		$	974,677
Total operating expenses	$	465,118		$	(296	)	$	464,822		$	1,006,132		$	29,048		$	1,035,180
Operating (Loss) Income	$	(24,066	)	$	296		$	(23,770	)	$	(5,693	)	$	(29,048	)	$	(34,741	)
(Loss) Income before income taxes and equity in earnings of affiliates	$	(28,074	)	$	296		$	(27,778	)	$	(10,638	)	$	(29,048	)	$	(39,686	)
Income tax (benefit) provision	$	(12,262	)	$	116		$	(12,146	)	$	(2,663	)	$	(11,716	)	$	(14,379	)
Net (Loss) Income	$	(14,335	)	$	180		$	(14,155	)	$	(7,597	)	$	(17,332	)	$	(24,929	)
Basic (loss) earnings per share	$	(0.34	)		—		$	(0.34	)	$	(0.18	)	$	(0.41	)	$	(0.59	)
Diluted (loss) earnings per share	$	(0.34	)		—		$	(0.34	)	$	(0.18	)	$	(0.41	)	$	(0.59	)

Note: Amounts may not cross foot due to rounding

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited)

	Nine Months Ended June 30,							Nine Months Ended June 30,
	2009							2008
(Thousands)	As Previously Reported		Adjustment			As Restated		As Previously Reported		Adjustment			As Restated
Gas purchases	$	1,881,058	$	(21,563	)	$	1,859,495	$	2,696,248	$	20,513		$	2,716,761
Total operating expenses	$	2,123,954	$	(21,563	)	$	2,102,391	$	2,919,943	$	20,513		$	2,940,456
Operating (Loss) Income	$	55,918	$	21,563		$	77,481	$	69,179	$	(20,513	)	$	48,666
(Loss) Income before income taxes and equity in earnings of affiliates	$	43,060	$	21,563		$	64,623	$	52,800	$	(20,513	)	$	32,287
Income tax (benefit) provision	$	12,880	$	8,416		$	21,296	$	19,225	$	(8,210	)	$	11,015
Net (Loss) Income	$	32,958	$	13,147		$	46,105	$	35,123	$	(12,303	)	$	22,820
Basic (loss) earnings per share	$	0.78	$	0.31		$	1.09	$	0.84	$	(0.29	)	$	0.55
Diluted (loss) earnings per share	$	0.77	$	0.31		$	1.08	$	0.84	$	(0.29	)	$	0.54

Note: Amounts may not cross foot due to rounding

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	Nine Months Ended June 30,									Nine Months Ended June 30,
	2009									2008
(Thousands)	As Previously Reported			Adjustment			As Restated			As Previously Reported			Adjustment			As Restated
Net Income	$	32,958		$	13,147		$	46,105		$	35,123		$	(12,303	)	$	22,820
Unrealized (gain) loss on derivatives	$	46,798		$	18,362		$	65,160		$	75,095		$	9,403		$	84,498
Deferred income taxes	$	4,316		$	8,416		$	12,732		$	8,203		$	(8,213	)	$	(10	)
Components of working capital	$	282,973		$	(39,925	)	$	243,048		$	(34,761	)	$	9,200		$	(25,561	)
Other non-current liabilities	$	(23,611	)		—		$	(23,611	)	$	24,850		$	1,913		$	26,763
Inventories	$	279,693		$	(18,811	)	$	260,882		$	73,666		$	(36,433	)	$	37,233
Gas purchases payable	$	(122,271	)	$	(22,256	)	$	(144,527	)	$	199,407		$	47,088		$	246,495
Other current assets	$	(14	)	$	1,142		$	1,128		$	(2,801	)	$	(1,455	)	$	(4,256	)
Total working capital	$	282,973		$	(39,925	)	$	243,048		$	(34,761	)	$	9,200		$	(25,561	)

Note: Amounts may not cross foot due to rounding

CONDENSED CONSOLIDATED BALANCE SHEETS

ASSETS

	(Unaudited)						(Audited)
	June 30,						September 30,
	2009						2008
(Thousands)	As Previously Reported		Adjustment		As Restated		As Previously Reported		Adjustment			As Restated
Gas in storage, at average cost	$	198,615	$	7,798	$	206,413	$	478,549	$	(11,012	)	$	467,537
Derivatives (current), at fair value	$	164,401	$	159	$	164,560	$	208,703	$	18,521		$	227,224
Other (current)	$	29,736	$	1,254	$	30,990	$	12,785	$	2,396		$	15,181
Total current assets	$	713,501	$	9,211	$	722,712	$	1,109,666	$	9,905		$	1,119,571
Total assets	$	2,304,088	$	9,211	$	2,313,299	$	2,625,392	$	9,905		$	2,635,297

Note: Amounts may not cross foot due to rounding

CAPITALIZATION AND LIABILITIES

	(Unaudited)							(Audited)
	June 30,							September 30,
	2009							2008
(Thousands)	As Previously Reported		Adjustment			As Restated		As Previously Reported		Adjustment		As Restated
Common stock equity	$	721,239	$	14,257		$	735,496	$	726,958	$	1,110	$	728,068
Total capitalization	$	1,178,910	$	14,257		$	1,193,167	$	1,182,075	$	1,110	$	1,183,185
Gas purchases payable	$	193,245	$	(14,173	)	$	179,072	$	315,516	$	8,084	$	323,600
Total current liabilities	$	579,652	$	(14,173	)	$	565,479	$	893,969	$	8,084	$	902,053
Deferred income taxes	$	224,471	$	9,127		$	233,598	$	239,703	$	711	$	240,414
Total noncurrent liabilities	$	545,526	$	9,127		$	554,653	$	549,348	$	711	$	550,059
Total capitalization and liabilities	$	2,304,088	$	9,211		$	2,313,299	$	2,625,392	$	9,905	$	2,635,297

Note: Amounts may not cross foot due to rounding

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

	Three Months Ended June 30,								Three Months Ended June 30,
	2009								2008
(Thousands)	As Previously Reported			Adjustment		As Restated			As Previously Reported			Adjustment			As Restated
Net (Loss) Income	$	(14,335	)	$	180	$	(14,155	)	$	(7,597	)	$	(17,332	)	$	(24,929	)
Comprehensive income	$	(14,372	)	$	180	$	(14,192	)	$	(7,343	)	$	(17,332	)	$	(24,675	)

Note: Amounts may not cross foot due to rounding

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

	Nine Months Ended June 30,						Nine Months Ended June 30,
	2009						2008
(Thousands)	As Previously Reported		Adjustment		As Restated		As Previously Reported		Adjustment			As Restated
Net Income	$	32,958	$	13,147	$	46,105	$	35,123	$	(12,303	)	$	22,820
Comprehensive income	$	32,781	$	13,147	$	45,928	$	35,367	$	(12,303	)	$	23,064

Note: Amounts may not cross foot due to rounding

3.	REGULATION

October Base Rate Order

As a result of increases in NJNG’s operation, maintenance and capital costs, on November 20, 2007, NJNG petitioned the New Jersey Board of Public Utilities (BPU) to increase base rates for delivery service by approximately $58.4 million, which included a return on NJNG’s equity component of 11.5 percent. This request was consistent with NJNG’s objectives of providing safe and reliable service to its customers and earning a market-based return on its regulated investments.

On October 3, 2008, the BPU unanimously approved and made effective the settlement of NJNG’s base rate case. As a result, NJNG received a revenue increase in its base rates of $32.5 million, which is inclusive of an approximate $13 million impact of a change to the Conservation Incentive Program (CIP) baseline usage rate, received an allowed return on equity component of 10.3 percent, reduced its depreciation expense component from 3 percent to 2.34 percent and reduced its annual depreciation expense by $1.6 million as a result of the amortization of previously recovered asset retirement obligations.

Conservation Incentive Program (CIP)

The CIP allows NJNG to recover utility gross margin variations related to both weather and customer usage. Recovery of such utility gross margin variations (filed for annually and recovered in the year following the end of the CIP usage year) is subject to additional conditions, including an earnings test and an evaluation of Basic Gas Supply Service (BGSS) related savings.

In May 2008, NJNG filed its Petition for the annual review of its CIP for recoverable CIP amounts for fiscal 2008, requesting an additional $6.8 million and approval to modify its CIP recovery rates effective October 1, 2008. The additional amount brought the total recovery requested to $22.4 million. The total recovery requested for fiscal 2008 includes amounts accrued and estimated through September 30, 2008. On October 3, 2008, the BPU approved the CIP petition on a provisional basis, effective the date of the order and on June 8, 2009, the BPU issued their final order approving the rates on a permanent basis. On April 1, 2009, NJNG submitted a proposal to extend its CIP mechanism, as currently structured, until October 1, 2010. The extension was requested due to the continuing nature of energy efficiency programs at the state and federal levels in concert with the issuance of the economic stimulus programs. If accepted by the BPU, the CIP would remain in effect for an additional year or until a final order is issued by the BPU.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

In June 2009, NJNG filed its annual BGSS and CIP filing for recoverable CIP amounts for fiscal 2009, requesting approval to modify its CIP recovery rates effective October 1, 2009, resulting in total annual recovery of $6.9 million. The total recovery requested for fiscal 2009 includes amounts accrued and estimated through September 30, 2009. As of June 30, 2009, NJNG has $6.3 million accrued under the CIP to be recovered in Regulatory Assets in the Unaudited Condensed Consolidated Balance Sheets.

In conjunction with the CIP, NJNG incurs costs related to its obligation to fund programs that promote customer conservation efforts during the three-year term of the CIP pilot program. As of June 30, 2009, NJNG had a remaining liability of $269,000 related to these programs.

Basic Gas Supply Service (BGSS)

BGSS is a BPU-approved rate mechanism designed to allow for the recovery of natural gas commodity costs. NJNG occasionally adjusts its periodic BGSS rates for its residential and small commercial customers to reflect increases or decreases in the cost of natural gas sold to customers.

In May 2008, NJNG filed for an increase to the periodic BGSS factor to be effective October 1, 2008, that would increase an average residential heating customer’s bill by approximately 18 percent due to an increase in the price of wholesale natural gas. Subsequent to the filing, wholesale natural gas prices moderated, and on September 22, 2008, NJNG, the Staff of the BPU and the Department of the Public Advocate, Division of Rate Counsel (Rate Counsel) signed an agreement for an increase to the periodic BGSS factor that would increase an average residential heating customer’s bill by approximately 8.9 percent. On October 3, 2008 and June 8, 2009, the BPU and Rate Counsel approved the BGSS increase on a provisional and final basis, respectively, effective the date of the orders.

In December 2008, NJNG provided notice that it would implement a $30 million BGSS-related rate credit that would lower residential and small commercial sales customers’ bills in January and February 2009. This rate credit was due primarily to a decline in wholesale commodity costs subsequent to the October 2008 BGSS price change. On February 20, 2009, NJNG provided notice to the BPU that its BGSS-related rate credit would be extended through March 31, 2009, to reduce BGSS charges by an additional $15 million.

In June 2009, NJNG filed its annual BGSS and CIP filing (2010 BGSS/CIP filing) proposing a decrease of 17.6 percent for the average residential heating customer of which 15.7 percent stems from the reduction in commodity costs based on the continuing decline in the wholesale natural gas market. The balance of the rate change is related to changes to the CIP rate, as discussed above, and a minor reduction to the rate related to collecting the remaining balance under the Weather Normalization Clause.

Other Incentive Programs

NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of utility gross margin-sharing programs that include off-system sales, capacity release, storage incentive and financial risk management (FRM) programs. In October 2007, the BPU reduced the sharing percentage of the margin generated by the FRM program retained by NJNG from 20 percent to 15 percent effective November 1, 2007. In October 2008, the BPU’s base rate order provided for the extension of the incentive programs through October 31, 2011, along with an expansion of the storage incentive and FRM programs.

Societal Benefits Clause (SBC) and Weather Normalization Clause (WNC)

The SBC is comprised of three primary components: a Universal Service Fund rider (USF), a Manufactured Gas Plant (MGP) Remediation Adjustment (RA), and the New Jersey Clean Energy Program (NJCEP). In February 2008, NJNG filed an application regarding its SBC proposing no change to the rates previously approved in October 2007 (February 2008 SBC filing). The BPU approved the February 2008 SBC filing on June 8, 2009. On January 27, 2009, NJNG filed an application regarding its SBC to increase its RA factor and its NJCEP factor while maintaining its effective rate on USF (January 2009 SBC filing). The January 2009 SBC filing is subject to BPU Staff and Rate Counsel review and must be approved by the BPU prior to implementing the new SBC rates.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

USF

Through the USF, eligible customers receive a credit toward their utility bill. The credits applied to eligible customers are recovered through the USF rider in the SBC. NJNG recovers carrying costs on deferred USF balances.

In June 2008, the natural gas utilities in New Jersey collectively filed with the BPU to increase the statewide USF recovery rate effective October 1, 2008. In the BPU’s October 21, 2008 order, the USF increase was approved on a provisional basis, effective October 24, 2008, and it also approved interest on USF deferred balances at the Treasury Constant Maturity 2-year rate, plus 60 basis points, net of deferred income tax, with the rate changing on a monthly basis. NJNG believes the increase has a negligible impact on customers.

In June 2009, the natural gas utilities in the State of New Jersey collectively filed with the BPU to decrease the statewide USF recovery rate effective October 1, 2009.The USF, as filed, will decrease the average monthly bill of a residential heating customer by 0.6 percent.

MGP

In October 2007, the BPU approved $14.7 million in eligible costs to be recovered annually for MGP remediation expenditures incurred through June 30, 2006. In June 2009, the BPU approved the February 2008 SBC filing, which proposed maintaining the current SBC rate and included recovery of MGP remediation expenditures incurred through June 30, 2007, resulting in an expected annual recovery of $17.7 million. The January 2009 SBC filing included MGP remediation expenditures incurred through June 30, 2008, resulting in an expected annual recovery of $20.7 million.

NJCEP

In October 2008, the BPU released a final order, updating state utilities’ funding obligations for NJCEP for the period from January 1, 2009 to December 31, 2012. NJNG’s share of the total funding requirement of $1.2 billion is $50.8 million. Accordingly, NJNG recorded the initial obligation and a corresponding regulatory asset at a present value of $44.3 in the Unaudited Condensed Consolidated Balance Sheets. NJNG’s annual obligation gradually increases from $10.3 million in fiscal 2009 to $15.9 million in fiscal 2012. As of June 30, 2009, NJNG had a $40 million obligation remaining.

The January 2009 SBC filing included an increase to the NJCEP factor. The proposed factor is expected to recover $12.9 million annually.

WNC

As of June 30, 2009, NJNG has a $129,000 unrecovered balance related to gross margin variations under the WNC incurred during the fiscal 2006 winter period. On October 3, 2008, the BPU provisionally approved a decrease to NJNG’s WNC rate, effective the date of the order, to fully recover its remaining WNC balance. As a result of an estimated WNC balance remaining to be recovered at September 30, 2009, NJNG included a request in its 2010 BGSS/CIP filing to reduce the WNC rate to recover the remaining balance in fiscal 2010.

Economic Stimulus

On January 20, 2009, NJNG filed two petitions with the BPU seeking approval to implement programs designed to both stimulate the state and local economy through infrastructure investments and encourage energy efficiency. The Accelerated Infrastructure Program (AIP) was approved on April 16, 2009, and allows NJNG to expedite $70.8 million of 14 previously planned infrastructure projects, maintaining safe and reliable service to NJNG’s customers while creating the opportunity for approximately 75 to 100 new jobs. Approved as a 2-year program, the AIP will be funded through an annual adjustment to customers’ base rates with the first adjustment expected in October 2010. The second filing, for an Energy Efficiency (EE) Program and associated cost recovery mechanism, requested BPU approval to implement various programs to encourage energy efficiency for residential and commercial customers. NJNG proposed to recover the EE Program costs over a 4-year period through a clause mechanism similar to the SBC. The EE Program stipulation was approved on July 1, 2009, for $21.1 million, if fully subscribed, including a return on investments and the recovery of operation and maintenance expense and income taxes ratably over four years. A true-up to actual EE program investments and costs is to be filed with the BPU on an annual basis. The effective date of the EE Program is August 1, 2009. Both the AIP and EE Programs include the recovery of NJNG’s overall weighted average cost of capital on these investments.

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Regulatory Assets & Liabilities

The Company had the following regulatory assets, all related to NJNG, on the Unaudited Condensed Consolidated Balance Sheets:

(Thousands)	June 30, 2009		September 30, 2008		Recovery Period
Regulatory assets–current
Underrecovered gas costs	$	—	$	27,994	Less than one year (1)
WNC		129		919	Less than one year (2)
CIP		6,189		22,463	Less than one year (3)
Total current	$	6,318	$	51,376
Regulatory assets–noncurrent
Remediation costs (Note 14)
Expended, net of recoveries	$	84,595	$	92,164	(4)
Liability for future expenditures		120,230		120,730	(5)
CIP		155		2,397	(6)
Deferred income and other taxes		12,523		12,726	Various (7)
Derivatives (Note 4)		47,295		49,610	(8)
Postemployment benefit costs (Note 11)		52,322		52,519	(9)
SBC/Clean Energy		42,756		10,524	Various (10)
Total noncurrent	$	359,876	$	340,670

(1)

Recoverable, subject to BPU approval, through BGSS, without interest.

(2)

Recoverable as a result of BPU approval in October 2008, without interest. This balance reflects the net results from winter period of fiscal 2006. No new WNC activity has been recorded since October 1, 2006 due to the existence of the CIP.

(3)

Recoverable or refundable, subject to BPU annual approval, without interest. Balance, as of June 30, 2009, includes approximately $1.6 million relating to the weather component of the calculation and approximately $4.6 million relating to the customer usage component of the calculation. Recovery from customers is designed to be one year from date of rate approval by the BPU.

(4)

Recoverable, subject to BPU approval, with interest over rolling 7-year periods.

(5)

Estimated future expenditures. Recovery will be requested when actual expenditures are incurred (see Note 14. Commitments and Contingent Liabilities – Legal Proceedings).

(6)

Recoverable or refundable, subject to BPU annual approval, without interest. Balance, as of June 30, 2009, includes approximately $155,000 relating to the customer usage component of the calculation.

(7)

Recoverable without interest, subject to BPU approval.

(8)

Recoverable, subject to BPU approval, through BGSS, without interest.

(9)

Recoverable or refundable, subject to BPU approval, without interest. Includes unrecognized service costs recorded in accordance with SFAS No. 158, Employers’ Accounting for Defined Benefit Pension and Other Postemployment Plans that NJNG has determined are recoverable in base rates charged to customers (see Note 11. Employee Benefit Plans).

(10)

Recoverable with interest, subject to BPU approval.

If there are any changes in regulatory positions that indicate the recovery of regulatory assets is not probable, the related cost would be charged to income in the period of such determination.

The Company had the following regulatory liabilities, all related to NJNG, on the Unaudited Condensed Consolidated Balance Sheets:

(Thousands)	June 30, 2009		September 30, 2008
Regulatory liabilities–current
Overrecovered gas costs (1)	$	30,842		—
Total current	$	30,842		—
Regulatory liabilities–noncurrent
Cost of removal obligation (2)	$	58,634	$	63,419
Total noncurrent	$	58,634	$	63,419

(1)

Refundable, subject to BPU approval, through BGSS with interest.

(2)

NJNG accrues and collects for cost of removal in rates. This liability represents collections in excess of actual expenditures. Approximately $22 million, including accretion of $1.1 million for the nine months ended June 30, 2009, of regulatory assets relating to asset retirement obligations have been netted against the cost of removal obligation as of June 30, 2009 (see Note 12. Asset Retirement Obligations).

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

4.	DERIVATIVE INSTRUMENTS

The Company and its subsidiaries are subject to commodity price risk due to fluctuations in the market price of natural gas. To manage this risk, the Company and its subsidiaries enter into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options, and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas. These contracts generally qualify as derivatives in accordance with SFAS 133, Accounting for Derivative Instruments and Hedging Activities. As a result, in accordance with the provisions of SFAS 133 all of the financial and certain of the Company’s physical derivative instruments are recorded at fair value in the Unaudited Condensed Consolidated Balance Sheets. The Company chooses not to designate its derivatives as hedging instruments pursuant to SFAS 133, and therefore changes in the fair value of the derivative instruments are recorded as a component of Gas purchases or Operating revenues, for NJRES and NJR Energy, respectively, in the Unaudited Condensed Consolidated Statements of Income as unrealized gains or losses. Changes in fair value of NJNG’s derivative instruments are recorded as a component of Regulatory assets or liabilities in the Unaudited Condensed Consolidated Balance Sheets, as these amounts will be recovered through future BGSS amounts as an increase or reduction to the cost of natural gas in NJNG’s tariff.

Effective October 1, 2007, the Company elected to discontinue the use of the “normal purchase normal sales” (normal) scope exception of SFAS 133 for all new physical commodity contracts entered into on or after October 1, 2007 by NJRES. For these contracts, the changes in fair value are included currently in earnings. Also, effective October 1, 2008, due to changes in the Company’s ability to assert physical delivery, the Company is no longer applying normal treatment to physical commodity contracts executed prior to October 1, 2007. Therefore, all NJRES physical commodity contracts are derivatives and are accounted for at fair value in the Unaudited Condensed Consolidated Balance Sheets, with changes in fair value included as a component of Operating revenue or Gas purchases, as appropriate, in the Unaudited Condensed Consolidated Statements of Income. The Company continues to apply the normal scope exception for all physical commodity contracts at NJNG and NJR Energy, and as a result the profit or loss on these contracts is not recorded until physical delivery occurs.

As a result of entering into transactions to borrow gas, commonly referred to as “park and loans,” an embedded derivative is created related to potential differences between the fair value of the amount borrowed and the fair value of the amount that may ultimately be repaid, based on changes in value in forward natural gas prices during the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a physical derivative transaction which is recorded at fair value on the balance sheet, with changes in value recognized in current period earnings.

As described in Note 1, General, NJR adopted the provisions of SFAS 161, which requires enhanced disclosures surrounding derivative activities. The additional quantitative and qualitative disclosures are included throughout this note. For a more detailed discussion of the Company’s fair value policies and level disclosures please see Note 5, Fair Value.

The following table reflects the fair value of NJR's derivative assets and liabilities recognized in its Unaudited Condensed Consolidated Balance Sheets as of June 30, 2009:

		Fair Value
(Thousands)	Balance Sheet Location	Asset Derivatives		Liability Derivatives
Derivatives not designated as hedging instruments under SFAS 133:

NJNG:
Financial derivative commodity contracts	Derivatives - Current	$	15,761	$	60,689
	Derivatives - Noncurrent		—		2,368
NJRES:
Physical forward commodity contracts	Derivatives - Current		24,418		17,505
	Derivatives - Noncurrent		5,968		386
Financial derivative commodity contracts	Derivatives - Current		122,368		72,738
	Derivatives - Noncurrent		6,000		6,095
NJR Energy:
Financial derivative commodity contracts	Derivatives - Current		2,013		433
	Derivatives - Noncurrent		1,377		151
Total fair value of derivatives		$	177,905	$	160,365

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

As previously discussed, the Company no longer applies the normal scope exception at NJRES and chooses not to apply the hedge accounting provisions of SFAS 133 to any of NJR and subsidiaries’ derivatives. As a result, any unrealized gains (losses) related to NJRES’ open financial and physical commodity contracts and NJR Energy’s financial derivatives are recognized in the Unaudited Condensed Consolidated Statements of Income as a component of Operating revenue or Gas purchases, as appropriate. NJRES’ utilizes financial derivatives to economically hedge the margin associated with the purchase of physical gas for injection into storage and the subsequent sale of physical gas at a later date. The gains (losses) on these financial transactions are recognized upon settlement in Gas purchases. The gains (losses) on the financial transactions that are economic hedges of the cost of the purchased gas are recognized prior to the gains (losses) on the physical transaction that is recognized when the natural gas is sold. Therefore, mismatches between the timing of recognizing realized gains or losses on the financial derivative instruments and the timing of the actual sale of the natural gas that is being economically hedged creates volatility in the results of NJRES, although the Company’s intended economic results relating to the entire transaction are unaffected.

Gains (losses) recognized at NJRES and NJR Energy since NJR’s adoption of SFAS 161 and included as a component of Operating revenues and Gas purchases, as noted below, for the three and six months ended June 30, 2009, are as follows:

(Thousands)	Location of Gain or (Loss) Recognized in Income on Derivative	Amount of Gain or (Loss) Recognized in Income on Derivative
Derivatives not designated as hedging instruments under SFAS 133:		Three Months Ended			Six Months Ended
		June 30, 2009
NJRES:
Physical commodity contracts	Operating revenues	$	8,301		$	16,340
Physical commodity contracts	Gas purchases		(882	)		8,044
Financial derivatives	Gas purchases		1,757			33,914
Subtotal NJRES		$	9,176			58,298
NJR Energy:
Financial derivatives	Operating revenues		62			(9,948	)
Total NJRES and NJR Energy unrealized and realized gains		$	9,238		$	48,350

Not included in the table above are (losses) associated with NJNG’s financial derivatives, that totaled $(1.7) million and $(35.1) million for the three and six months ended June 30, 2009, respectively. These derivatives are part of its 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 NJNG’s financial derivatives are deferred in Regulatory Assets or Liabilities and there is no impact to earnings.

As of June 30, 2009, NJNG, NJRES and NJR Energy had the following outstanding long (short) derivatives:

		Volume (Bcf)
NJNG	Futures		8.4
	Swaps		(0.3	)
	Options		11.5
NJRES	Futures		(16.3	)
	Swaps		(18.0	)
	Options		2.5
	Physical		54.9
NJR Energy	Swaps		3.2

Generally, exchange-traded contracts require posted collateral, referred to as margin, usually in the form of cash. The amount of margin required is comprised of a fixed initial amount based on the contract and a variable amount based on market price movements from the initial trade price. The Company maintains broker margin accounts for NJNG and NJRES. The balances are as follows:

(Thousands)	Balance Sheet Location	June 30, 2009			September 30, 2008
NJNG broker margin deposit	Broker margin - Current Assets	$	49,204		$	41,277
NJRES broker margin (liability)	Broker margin - Current Liabilities	$	(9,185	)	$	(29,072	)

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Wholesale Credit Risk

NJNG, NJRES and NJR Energy are exposed to credit risk as a result of their wholesale marketing activities. NJR monitors and manages the credit risk of its wholesale marketing operations through credit policies and procedures that management believes reduce overall credit risk. These policies include a review and evaluation of current and prospective counterparties’ financial statements and/or credit ratings, daily monitoring of counterparties’ credit limits and exposure, daily communication with traders regarding credit status and the use of credit mitigation measures, such as collateral requirements and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin deposit. Collateral may be requested due to NJR’s election not to extend credit or because exposure exceeds defined thresholds. Most of NJR’s wholesale marketing contracts contain standard netting provisions. These contracts include those governed by the International Swaps and Derivatives Association (ISDA) and the North American Energy Standards Board (NAESB). The netting provisions refer to payment netting, whereby receivables and payables with the same counterparty are offset and the resulting net amount is paid to the party to which it is due.

As a result of the inherent volatility in the prices of natural gas commodities and derivatives, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty failed to perform the obligations under its contract (for example, failed to deliver or pay for natural gas), then the Company could sustain a loss.

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of June 30, 2009. Internally-rated exposure applies to counterparties that are not rated by Standard & Poor’s (S&P) or Moody’s Investors Service, Inc. (Moody’s). In these cases, the company’s or guarantor’s financial statements are reviewed by the Company, and similar methodologies and ratios used by S&P and/or Moody’s are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts plus any outstanding receivable for the value of natural gas delivered for which payment has not yet been received. The amounts presented below have not been reduced by any collateral received or netting and exclude accounts receivable for retail natural gas sales and services.

(Thousands)	Gross Credit Exposure
Investment grade	$	119,929
Noninvestment grade		13,793
Internally rated investment grade		19,854
Internally rated noninvestment grade		4,118
Total	$	157,694

Conversely, certain of NJRES’, NJNG’s and NJR Energy’s derivative instruments are tied to agreements containing provisions that would require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in individual counterparty agreements and can result in cash payments if NJNG’s credit rating were to fall below its current level. NJNG’s credit rating, with respect to Standard and Poor’s, reflects the overall corporate credit profile. Specifically, most, but not all, of these additional payments will be triggered if NJNG’s debt is downgraded by the major credit agencies, regardless of investment grade status. As well, some of these agreements include threshold amounts that would result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in relevant counterparty agreements. Other provisions include payment features that are not specifically tied to ratings, but are based on certain financial metrics.

Collateral amounts associated with any of these conditions, are determined based on a sliding scale and are contingent upon the degree to which the Company’s credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position on June 30, 2009, is $33.1 million for which the Company has not posted any collateral. If all the thresholds related to the credit-risk-related contingent features underlying these agreements were invoked on June 30, 2009, the Company would not be required to post any additional collateral to its counterparties. This amount differs from the Company’s net derivative liability because the credit agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted.

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

5.	FAIR VALUE

The fair value of cash and temporary investments, accounts receivable, accounts payable, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. The estimated fair value of long-term debt, excluding current maturities and capital lease obligations, is based on quoted market prices for similar issues and is as follows:

	June 30,		September 30,
(Thousands)	2009		2008
Carrying value	$	399,800	$	399,800
Fair market value	$	402,600	$	351,400

Adoption of SFAS 157

As noted in Note 1, General, NJR adopted SFAS 157 effective October 1, 2008 and has applied the provisions to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. SFAS 157 defines and establishes a framework for measuring fair value. SFAS 157 requires that companies consider assumptions market participants would make when pricing assets and liabilities that are required to be recognized at fair value in accordance with previously issued accounting pronouncements.

SFAS 157 also requires additional disclosures that are intended to convey the reliability of price inputs used to determine fair value. To facilitate this, SFAS 157 established a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and include the following:

Level 1

Unadjusted quoted prices for identical assets or liabilities in active markets; NJR’s Level 1 assets and liabilities include primarily exchange traded financial derivative contracts and listed equities;

Level 2

Significant price data, other than Level 1 quotes, that is observed either directly or indirectly; NJR’s level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components. These additional adjustments are not considered to be significant to the ultimate recognized values.

Level 3

Inputs derived from a significant amount of unobservable market data; these include NJR’s best estimate of fair value and are derived primarily through the use of internal valuation methodologies. Certain of NJR’s physical commodity contracts that are to be delivered to inactively traded points on a pipeline are included in this category.

NJNG’s, NJRES’ and NJR Energy’s financial derivatives portfolios consist mainly of futures, options and swaps. NJR primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market, therefore, the primary source for its price inputs is the New York Mercantile (NYMEX) exchange. NJRES also uses Natural Gas Exchange (NGX) for Canadian delivery points and Platts and NYMEX ClearPort for certain over-the-counter physical forward commodity contracts. However, NJRES also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In these cases, NJRES’ policy is to use the best information available to determine fair value based on internal pricing models, which include estimates extrapolated from broker quotes or pricing services. As of June 30, 2009, less than one percent of the total fair value of NJRES’ derivative assets and liabilities was derived using such inputs.

NJR Energy uses NYMEX settlement prices to value its long-dated swap contracts. NJR also has available for sale securities and other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.

When NJR determines fair values, measurements are adjusted, as needed, for credit risk associated with counterparties, as well as its own credit risk. NJR determines these adjustments by using historical default probabilities that correspond to the applicable Standard and Poor’s issuer ratings, while also taking into consideration collateral and netting arrangements that serve to mitigate risk.

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The adoption of SFAS 157 did not have any impact on NJR’s financial condition or results of operations. Assets and liabilities measured at fair value on a recurring basis as of June 30, 2009, are summarized as follows:

	Quoted Prices in Active Markets for Identical Assets		Significant Other Observable Inputs		Significant Unobservable Inputs
(Thousands)	(Level 1)		(Level 2)		(Level 3)		Total
Assets:
Physical forward commodity contracts	$	—	$	30,385	$	—	$	30,385
Financial derivative contracts		102,568		44,952		—		147,520
Available for sale securities (1)		7,780		—		—		7,780
Other assets		1,365		—		—		1,365
Total assets at fair value	$	111,713		75,337	$	—	$	187,050

Liabilities:
Physical forward commodity contracts	$	—	$	17,892	$	—	$	17,892
Financial derivative contracts		107,723		34,750		—		142,473
Other liabilities		1,365		—		—		1,365
Total liabilities at fair value	$	109,088	$	52,642	$	—	$	161,730

(1)

Included in Investments in equity investees in the Condensed Consolidated Balance Sheets.

A reconciliation of the beginning and ending balances of NJRES’ derivatives measured at fair value based on significant unobservable inputs as of June 30, 2009, is as follows:

	Fair Value Measurements Using
	Significant Unobservable Inputs
	(Level 3)
(Thousands)	Three Months Ended			Nine Months Ended
Beginning balance	$	2		$	937
Total gains realized and unrealized (1)		—			320
Purchases, sales, issuances and settlements, net		(2	)		(774	)
Net transfers in and/or out of level 3		—			(483	)
Ending balance	$	—		$	—

Net unrealized gains included in net income relating to derivatives still held at June 30, 2009	$	—		$	—

(1)

Gains recognized in Operating revenues and Gas purchases for the nine months ended June 30, 2009 are $77,000 and $243,000, respectively.

NJR will prospectively apply the provisions of SFAS 157 to its pension assets and non-financial assets and liabilities during fiscal 2010.

6.	INVESTMENTS IN EQUITY INVESTEES

NJR’s Investments in equity investees include the following investments:

(Thousands)	June 30, 2009		September 30, 2008
Steckman Ridge	$	127,994	$	84,285
Iroquois		20,537		23,604
Other		7,780		8,092
Total	$	156,311	$	115,981

NJR’s investment in Steckman Ridge increased $43.7 million during the nine months ended June 30, 2009, including cash investments of $40.2 million and capitalized costs and interest of $3.5 million. Steckman Ridge became partially operational and had minimal activity during the third quarter of fiscal 2009.

NJR uses the equity method of accounting for its investments in Steckman Ridge and Iroquois.

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Other consists of an investment in equity securities of a publicly traded energy company and is accounted for as available for sale securities, with any change in the fair value of such investment recorded in Accumulated other comprehensive income, a component of Common stock equity. Unrealized (losses) gains associated with these equity securities were approximately $(106,000), net of tax of $74,000, and $336,000, net of tax of $(235,000), for the nine months ended June 30, 2009 and 2008, respectively.

The following tables are summarized financial information for Iroquois:

	Three Months Ended June 30,				Nine Months Ended June 30,
(Millions)	2009		2008		2009		2008
Operating revenues	$	52.2	$	40.9	$	145.0	$	124.3
Operating income	$	31.0	$	20.6	$	83.1	$	66.0
Net income	$	14.1	$	8.5	$	38.1	$	27.5

(Millions)	June 30, 2009		September 30, 2008
Current assets	$	196.3	$	64.2
Noncurrent assets	$	770.0	$	729.2
Current liabilities	$	235.3	$	39.3
Noncurrent liabilities	$	264.5	$	348.9

7.	EARNINGS PER SHARE

The following table sets forth the calculation of the Company’s basic and diluted earnings per share:

	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands, except per share amounts)	2009			2008			2009		2008
Net income, as reported	$	(14,155	)	$	(24,929	)	$	46,105	$	22,820
Basic earnings per share
Weighted average shares of common stock outstanding–basic		42,049			41,949			42,175		41,822
Basic earnings per common share	$	(0.34	)	$	(0.59	)	$	1.09	$	0.55
Diluted earnings per share
Weighted average shares of common stock outstanding–basic		42,049			41,949			42,175		41,822
Incremental shares (1)		—			—			372		215
Weighted average shares of common stock outstanding–diluted		42,049			41,949			42,547		42,037
Diluted earnings per common share (2)	$	(0.34	)	$	(0.59	)	$	1.08	$	0.54

(1)

Incremental shares consist of stock options, stock awards and performance units.

(2)

Incremental shares were not included in the computation of diluted loss per common share for the three months ended June 30, 2009 and 2008, as their effect would have been anti-dilutive.

DEBT

NJR

On March 15, 2009, NJR repaid its $25 million, 3.75 percent, Unsecured Senior notes at maturity.

On December 13, 2007, NJR entered into a $325 million unsecured committed credit facility expiring in December 2012. As of June 30, 2009, NJR had $48.6 million in borrowings outstanding under the facility.

As of June 30, 2009, NJR has a $23 million letter of credit outstanding on behalf of NJRES, which is used for margin requirements for natural gas transactions and will expire on December 31, 2009.

NJR also has a $675,000 letter of credit outstanding on behalf of CR&R, which will expire on December 3, 2009. The letter of credit is in place to support development activities.

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NJNG

On November 1, 2008, NJNG repaid its $30 million, 6.27 percent, Series X First Mortgage bonds at maturity.

In October 2007, NJNG entered into an agreement for standby letters of credit that may be drawn upon through December 15, 2009, for up to $50 million. As of June 30, 2009, no letters of credit have been issued under this agreement. These letters of credit would not reduce the amount available to be borrowed under NJNG’s credit facility.

As of June 30, 2009, NJNG has a $250 million committed credit facility with several banks, expiring in December 2009. This facility is used to support NJNG’s commercial paper program. NJNG had no borrowings outstanding under this facility as of June 30, 2009.

NJNG received $6.3 million and $7.5 million in December 2008 and 2007, respectively, in connection with the sale-leaseback of its natural gas meters. This sale-leaseback program is expected to be continued on an annual basis.

NJNG is obligated with respect to loan agreements securing six series of variable rate bonds totaling approximately $97 million of variable-rate debt backed by securities issued by the New Jersey Economic Development Authority (EDA). The EDA bonds are commonly referred to as auction rate securities (ARS) and have an interest rate reset every 7 or 35 days, depending upon the applicable series. On those dates, an auction is held for the purposes of determining the interest rate of the securities. The interest rate associated with the NJNG variable-rate debt is based on the rates on the EDA ARS. For the nine months ended June 30, 2009, all of the auctions surrounding the EDA ARS have failed, resulting in those bonds bearing interest at their maximum rates, defined as the lesser of (i) 175 percent of 30-day LIBOR or (ii) 10 to 12 percent per annum, as applicable to such series of ARS. As of June 30, 2009, the 30-day LIBOR rate was 0.3 percent. While the failure of the ARS auctions does not signify or constitute a default by NJNG, the EDA ARS does impact NJNG’s borrowing costs of the variable-rate debt. As such, NJNG currently has a weighted average interest rate of 0.6 percent as of June 30, 2009, compared with a weighted average interest rate of 4.6 percent as of September 30, 2008. There can be no assurance that the EDA ARS will have enough market liquidity to avoid failed auctions in the future.

In October 2005, NJNG entered into a loan agreement under which the EDA loaned NJNG the proceeds from $35.8 million of tax-exempt EDA Bonds. NJNG deposited $15 million of the proceeds into a construction fund to finance subsequent construction in the northern division of NJNG’s territory. NJNG drew down $10.8 million from the construction fund prior to fiscal year 2009 and drew down the remaining $4.2 million in December 2008 .

Neither NJNG’s assets nor the results of its operations are obligated or pledged to support the NJR or NJRES credit facilities.

NJRES

As of June 30, 2009, NJRES had a 3-year, $30 million committed credit facility that expires in October 2009 with a multinational financial institution. There were no borrowings under this facility as of June 30, 2009.

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

A summary of NJR’s and NJNG’s long-term debt, committed credit facilities, which require annual commitment fees, and NJRES’ committed facility that does not require a commitment fee, are as follows:

	June 30,			September 30,
(Thousands)	2009			2008
NJR
Long - term debt	$	50,000		$	75,000
Bank credit facilities	$	325,000		$	325,000
Amount outstanding under bank credit facilities at end of period
Notes payable to banks	$	48,600		$	32,700
Weighted average interest rate at end of period
Notes payable to banks		0.72	%		2.46	%
NJNG
Long - term debt (1)	$	349,800		$	379,800
Bank credit facilities	$	250,000		$	250,000
Amount outstanding under bank credit facilities at end of period
Commercial paper		—		$	145,500
Weighted average interest rate at end of period
Commercial paper		—			2.31	%
NJRES
Bank credit facilities	$	30,000		$	30,000
Amount outstanding under bank credit facilities at end of period
Notes payable to banks		—			—
Weighted average interest rate at end of period
Notes payable to banks		—			—

(1)

Long - term debt excludes lease obligations of $63.8 million and $60.4 million at June 30, 2009 and September 30, 2008, respectively.

9.	CAPITALIZED FINANCING COSTS AND DEFERRED INTEREST

Included in the Condensed Consolidated Balance Sheets are capitalized amounts associated with NJR’s Allowance for funds used during construction, (AFUDC), which are recorded in Utility plant, as well as capitalized interest recorded in Real estate properties and other and Investments in equity investees. Corresponding amounts recognized in Interest expense and Other income, as appropriate, in the Unaudited Consolidated Statements of Income are as follows:

	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands)	2009			2008			2009			2008
AFUDC – Utility plant	$	402		$	244		$	832		$	871
Weighted average rate		5.38	%		4.8	%		3.57	%		4.8	%

Capitalized interest – Real estate properties and other	$	—		$	14		$	—		$	79
Weighted average interest rates		—	%		3.01	%		—	%		3.99	%

Capitalized interest – Investments in equity investees	$	214		$	827		$	1,884		$	2,513
Weighted average interest rates		4.95	%		5.58	%		5.15	%		5.73	%

As a result of the BPU’s Base Rate order issued in October 2008, NJNG implemented certain rate design changes, including a change to its AFUDC calculation and a return on equity rate of 10.3 percent (see Note 3. Regulation). Effective October 3, 2008, NJNG is allowed to recover an incremental cost of equity component during periods when its short-term debt balances are lower than its construction work in progress.

Table of Contents

New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

As of April 2009, due to a reduction in NJNG’s commercial paper borrowings relative to its Construction Work in Progress (CWIP), NJNG’s capitalized costs included incremental equity as allowed, of $233,000 for the three and nine months ended June 30, 2009.

NJR, through its CR&R subsidiary, capitalizes interest associated with the development and construction of its commercial buildings. Interest is also capitalized associated with the acquisition, development and construction of a natural gas storage facility through NJR’s equity investment in Steckman Ridge (see Note 6. Investments in Equity Investees).

Pursuant to a BPU order, NJNG is permitted to recover carrying costs on uncollected balances related to SBC program costs, which include NJCEP, RAC and USF expenditures. Accordingly, Other income included $482,000 and $515,000 of interest related to these SBC program costs for the three months ended June 30, 2009 and 2008, respectively, and $1.5 million and $1.9 million for the nine months ended June 30, 2009 and 2008, respectively.

10.	STOCK-BASED COMPENSATION

On November 11, 2008, the Company granted 106,730 restricted shares that vested immediately. On the same date, the Company also granted 8,481 shares that vested immediately and were issued on November 17, 2008. On January 21, 2009, the members of the Board of Directors were issued 12,000 shares for their annual retainer. On March 11, 2009, the Company granted 46,500 restricted shares two-thirds of which vested on October 1, 2009, and one-third of which may vest on October 1, 2010, subsequent to meeting certain performance milestones. On April 7, 2009, the Company granted 1,500 restricted shares of which fifty percent will vest on April 7, 2010, and the remaining fifty percent will vest on April 7, 2011.

As of June 30, 2009, 2,396,715 and 95,203 shares remain available for future awards to employees and directors, respectively.

Included in Operation and maintenance expense is $929,000 and $750,000 for the three months and $2.1 million and $2 million for the nine months ended June 30, 2009 and 2008, respectively, related to stock-based compensation. As of June 30, 2009, there remains $2.4 million of deferred compensation related to unvested shares and options, which is expected to be recognized over the next 2 years.

11.	EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans (OPEB)

The components of the net periodic cost for pension benefits, including NJR’s Pension Equalization Plan, and OPEB costs (principally health care and life insurance) for employees and covered dependents were as follows:

	Pension												OPEB
	Three Months Ended June 30,						Nine Months Ended June 30,						Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands)	2009			2008			2009			2008			2009			2008			2009			2008
Service cost	$	678		$	728		$	2,034		$	2,185		$	432		$	436		$	1,296		$	1,360
Interest cost		1,937			1,648			5,811			4,945			1,014			810			3,043			2,441
Expected return on plan assets		(2,188	)		(2,183	)		(6,564	)		(6,548	)		(499	)		(627	)		(1,497	)		(1,837	)
Recognized actuarial loss		138			275			416			826			267			181			801			624
Prior service cost amortization		14			14			42			42			20			19			59			58
Transition obligation amortization		—			—			—			—			89			89			268			267
Net periodic cost	$	579		$	482		$	1,739		$	1,450		$	1,323		$	908		$	3,970		$	2,913

For fiscal 2009, the Company has no minimum pension funding requirements. However, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in demographic factors. On June 12, 2009, NJR made a discretionary contribution of $1 million to the Pension plan. It is anticipated that the annual funding level to the OPEB plans will range from $1.2 million to $1.4 million over the next five years. Additional contributions may be made based on market conditions and various assumptions.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

12.	ASSET RETIREMENT OBLIGATIONS (ARO)

NJR recognizes AROs related to the costs associated with cutting and capping its main and service gas distribution pipelines of NJNG, which is required by New Jersey law when taking such gas distribution pipelines out of service.

The following is an analysis of the change in the ARO liability for the nine month period ended June 30, 2009:


(Thousands)
Balance at October 1, 2008	$	24,416
Accretion		1,113
Additions		—
Retirements		(508	)
Balance at June 30, 2009	$	25,021

Accretion amounts are not reflected as an expense on NJR’s Unaudited Condensed Consolidated Statements of Income, but rather are deferred as a regulatory asset and netted against NJNG’s regulatory liabilities, for presentation purposes, on the Unaudited Condensed Consolidated Balance Sheet.

13.	INCOME TAXES

As of September 30, 2008, the Company had a FIN 48 (Reserve for Uncertain Tax Positions) balance of $6.5 million. During the first quarter of fiscal year 2009, the Company settled a tax court case with the State of New Jersey, which resulted in a $2.7 million decrease to the reserve balance.

During the second quarter of fiscal 2009, the Company settled the September 30, 2005 Internal Revenue Service (IRS) tax audit. The settlement resulted in an additional reduction to the remaining FIN 48 balance of $3.8 million bringing it to its current balance of zero. The prior balance of $3.8 million related to one issue which has been settled and resulted in no changes to the Company’s tax liability related to the issue.

NJR accrues penalties and interest related to its FIN 48 and other tax issues as a component of the income tax provision, therefore, the ultimate settlement of the various tax issues will impact the effective tax rate to the extent that the amount of penalties and interest assessed is different than the amounts originally accrued. The tax effect of the currently accrued and settled issues will have no impact on the effective tax rate.

Currently the Company has no reason to believe that there will be any new additions to the FIN 48 reserve.

14.	COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through 2023, for the supply, storage and delivery of natural gas. These contracts include current annual fixed charges of approximately $95 million at current contract rates and volumes, which are recoverable through the BGSS.

For the purpose of securing adequate storage and pipeline capacity, NJRES enters into storage and pipeline capacity contracts, which require the payment of certain demand charges by NJRES, in order to maintain the ability to access such natural gas storage or pipeline capacity, during a fixed time period, which generally range from one to five years. Demand charges are based on established rates as regulated by the Federal Energy Regulatory Commission (FERC). These demand charges represent commitments to pay storage providers or pipeline companies for the right to store and transport natural gas utilizing their respective assets. As of June 30, 2009, NJRES had contractual obligations for current annual demand charges related to storage contracts and pipeline capacity contracts of $38.8 million and $43.5 million, respectively.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Commitments as of June 30, 2009, for natural gas purchases and future demand fees, for the next five fiscal year periods, are as follows:

(Thousands)	2009		2010		2011		2012		2013		Thereafter
NJRES:
Natural gas purchases	$	154,206	$	298,133	$	125,513	$	127,306	$	10,734	$	—
Pipeline demand fees		15,727		35,427		20,924		10,106		10,459		31,525
Storage demand fees		10,393		33,728		16,136		10,616		6,405		4,410
Sub-total NJRES	$	180,326	$	367,288	$	162,573	$	148,028	$	27,598	$	35,935
NJNG:
Natural gas purchases	$	17,463	$	22,987	$	1,644	$	—	$	—	$	—
Pipeline demand fees		14,910		77,435		81,927		75,854		74,874		321,797
Storage demand fees		5,477		21,910		18,398		13,310		10,415		6,713
Sub-total NJNG	$	37,850	$	122,332	$	101,969	$	89,164	$	85,289	$	328,510
Total	$	218,176	$	489,620	$	264,542	$	237,192	$	112,887	$	364,445

Costs for storage and pipeline demand fees, included as a component of Gas purchases on the Unaudited Condensed Consolidated Statements of Income, are as follows:

	Three Months Ended June 30,				Nine Months Ended June 30,
(Millions)	2009		2008		2009		2008
NJRES	$	30.1	$	29.1	$	87.9	$	86.9
NJNG		20.1		17.9		62.9		56.0
Total	$	48.6	$	47.3	$	149.7	$	144.4

NJNG’s capital expenditures are estimated at $87.1 million for fiscal 2009, including $6 million related to AIP construction costs, of which approximately $56.9 million has been committed. Capital expenditures consist primarily of NJNG’s construction program to support customer growth, maintenance of its distribution and transmission systems, replacements of infrastructure under pipeline safety regulations, an automated meter reading installation project and AIP.

The Company’s future minimum lease payments under various operating leases are less than $3.0 million annually for the next five years and $1.4 million in the aggregate for all years thereafter.

Guarantees

As of June 30, 2009, there were NJR guarantees covering approximately $356 million of natural gas purchases and demand fee commitments of NJRES and NJNG not yet reflected in Accounts payable on the Unaudited Condensed Consolidated Balance Sheet.

In fiscal 2009, the Company entered into agreements to lease vehicles over a five-year term, which qualify as operating leases. These agreements contain provisions that could require the Company to make additional cash payments at the end of the term for a portion of the residual value of the vehicles. As of June 30, 2009, the present value of the liability recognized on the Condensed Consolidated Balance Sheets is $292,000. In the event performance under the guarantee is required, the Company’s maximum future payment would be $475,000.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of three Manufactured Gas Plant (MGP) sites, dating back to gas operations in the late 1800s and early 1900s, which contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the New Jersey Department of Environmental Protection (NJDEP), as well as participating in various studies and investigations by outside consultants to determine the nature and extent of any such contaminated residues and to develop appropriate programs of remedial action, where warranted, under Administrative Consent Orders or Memoranda of Agreement with the NJDEP.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

NJNG may, subject to BPU approval, recover its remediation expenditures, including carrying costs, over rolling 7-year periods pursuant to a Remediation Adjustment (RA) approved by the BPU. In October 2007, the BPU approved $14.7 million in eligible costs to be recovered annually for MGP remediation expenditures incurred through June 30, 2006. In February 2008, NJNG filed an application regarding its SBC which included MGP remediation expenditures incurred through June 30, 2007, resulting in an expected annual recovery of $17.7 million. The February 2008 filing was approved by the BPU on a permanent basis on June 10, 2009. On January 27, 2009, NJNG filed an application regarding its SBC including MGP remediation expenditures incurred through June 30, 2008 resulting in an expected annual recovery of $20.7 million. As of June 30, 2009, $84.6 million of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in Regulatory assets on the Unaudited Condensed Consolidated Balance Sheet.

In September 2008, NJNG updated an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the review that total future expenditures to remediate and monitor the three MGP sites for which it is responsible will range from approximately $120.2 million to $177.2 million. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. However, NJNG expects actual costs to differ from these estimates. Where it is probable that costs will be incurred, but the information is sufficient only to establish a range of possible liability, and no point within the range is more likely than any other, it is NJNG’s policy to accrue the lower end of the range. Accordingly, NJNG has recorded an MGP remediation liability and a corresponding Regulatory asset of $120.2 million on the Unaudited Condensed Consolidated Balance Sheet. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries.

NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related cost would be charged to income in the period of such determination. However, because recovery of such costs is subject to BPU approval, there can be no assurance as to the ultimate recovery through the RAC or the impact on the Company’s results of operations, financial position or cash flows, which could be material.

General

The Company is party to various other claims, legal actions and complaints arising in the ordinary course of business. In the Company’s opinion, the ultimate disposition of these matters will not have a material adverse effect on its financial condition, results of operations or cash flows.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

15.	BUSINESS SEGMENT AND OTHER OPERATIONS DATA

NJR organizes its business based on its products and services as well as regulatory environment. As a result, the Company chooses to manage the businesses through the following reportable segments and other operations: the Natural Gas Distribution segment consists of regulated energy and off-system, capacity and storage management operations; the Energy Services segment consists of unregulated wholesale energy operations; the Retail and Other operations consist of appliance and installation services, commercial real estate development, investments and other corporate activities.

Information related to the Company’s various business segments and other operations, excluding capital expenditures at NJNG of $55.2 million and at Retail and Other of $356,000 is detailed below.

	(Unaudited)						(Unaudited)
	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands)	2009			2008			2009			2008
Operating Revenues
Natural Gas Distribution	$	148,826		$	179,511		$	958,995		$	940,689
Energy Services		283,439			801,628			1,219,296			2,009,751
Segment subtotal		432,265			981,139			2,178,291			2,950,440
Retail and Other		8,832			19,344			3,828			38,834
Intersegment revenues (1)		(45	)		(44	)		(2,247	)		(152	)
Total	$	441,052		$	1,000,439		$	2,179,872		$	2,989,122
Depreciation and Amortization
Natural Gas Distribution	$	7,668		$	9,488		$	22,120		$	28,053
Energy Services		51			50			153			156
Segment subtotal		7,719			9,538			22,273			28,209
Retail and Other		161			142			476			391
Total	$	7,880		$	9,680		$	22,749		$	28,600
Interest Income (2)
Natural Gas Distribution	$	772		$	(91	)	$	1,934		$	2,519
Energy Services (3)		172			68			509			239
Segment subtotal		944			(23	)		2,443			2,758
Retail and Other		289			124			308			250
Intersegment interest income (1)		(168	)		—			(487	)		—
Total	$	1,065		$	101		$	2,264		$	3,008
Interest Expense, net of capitalized interest
Natural Gas Distribution	$	4,028		$	4,146		$	14,692		$	15,641
Energy Services (3)		73			738			244			2,502
Segment subtotal		4,101			4,884			14,936			18,143
Retail and Other		1,254			298			1,504			1,541
Intersegment interest expense (1)		(168	)		—			(487	)		—
Total	$	5,187		$	5,182		$	15,953		$	19,684
Income Tax Provision (Benefit)
Natural Gas Distribution	$	2,369		$	3,218		$	40,472		$	34,378
Energy Services		(14,764	)		(22,768	)		(11,004	)		(30,817	)
Segment subtotal		(12,395	)		(19,550	)		29,468			3,561
Retail and Other		249			5,171			(8,172	)		7,454
Total	$	(12,146	)	$	(14,379	)	$	21,296		$	11,015
Net Financial Earnings
Natural Gas Distribution	$	4,134		$	147		$	68,796		$	50,987
Energy Services		(4,484	)		(5,630	)		35,977			56,979
Segment subtotal		(350	)		(5,483	)		104,773			107,966
Retail and Other		1,596			1,397			1,379			2,253
Total	$	1,246		$	(4,086	)	$	106,152		$	110,219

(1)	Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation

(2)	Included in Other income in the Unaudited Condensed Consolidated Statement of Income

(3)	Amounts have been restated to reflect a reclassification between interest income and interest expense, which were previously netted.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The chief operating decision maker of the Company is the Chief Executive Officer (CEO). The CEO uses net financial earnings as a measure of profit or loss in measuring the results of the Company’s segments and operations. A reconciliation of consolidated net financial earnings to consolidated net income, for the three and nine months ended June 30, 2009 and 2008, respectively, is as follows:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(Thousands)	2009			2008			2009		2008
Consolidated Net Financial Earnings (Loss)	$	1,246		$	(4,086	)	$	106,152	$	110,219
Less:
Unrealized loss from derivative instruments, net of taxes		6,981			21,428			39,557		97,782
Realized loss (gain) from derivative instruments related to natural gas inventory, net of taxes		8,420			(585	)		20,490		(10,383	)
Consolidated Net (Loss) Income	$	(14,155	)	$	(24,929	)	$	46,105	$	22,820

The company uses derivative instruments as economic hedges of purchases and sales of physical gas inventory. For GAAP purposes, these derivatives are recorded at fair value and related changes in fair value are included in reported earnings. Revenues and cost of gas related to physical gas flow is recognized as the gas is delivered to customers. Consequently, there is a mismatch in the timing of earnings recognition between the economic hedges and physical gas flows. Timing differences occur in two ways:

Unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to physical gas inventory flows; and

Unrealized gains and losses of prior periods are reclassified as realized gains and losses when derivatives are settled in the same period as physical gas inventory movements occur.

Net financial earnings is a measure of the earnings based on eliminating these timing differences, to effectively match the earnings effects of the economic hedges with the physical sale of gas. Consequently, to reconcile between GAAP and net financial earnings, current period unrealized gains and losses on the derivatives are excluded from net financial earnings as a reconciling item. Additionally, realized derivative gains and losses are also included in current period net income, however net financial earnings include only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical gas flows.

The Company’s assets for the various business segments and business operations are detailed below:

	June 30,			September 30,
(Thousands)	2009			2008
Assets at end of period:
Natural Gas Distribution	$	1,745,411		$	1,761,964
Energy Services		374,500			699,897
Segment Subtotal		2,119,911			2,461,861
Retail and Other		215,343			231,551
Intercompany Assets (1)		(21,955	)		(58,115	)
Total	$	2,313,299		$	2,635,297

(1) Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation

NJRES’ assets decreased 46 percent from September 30, 2008 to June 30, 2009, due primarily to lower inventory values resulting from a decline in commodity prices.

For the nine months ended June 30, 2009, NJRES had one customer who represented more than 10 percent of its total revenue. Management believes that the loss of this customer would not have a material effect on its financial position, results of operations or cash flows as an adequate number of alternative counterparties exist.

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New Jersey Resources Corporation

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

16.	RELATED PARTY TRANSACTIONS

During the three months ended June 30, 2009, NJRES entered into park and loan agreements and firm storage contracts with Steckman Ridge, an affiliated regulated natural gas storage facility, for up to 2 Bcf of natural gas storage with various terms ranging from April 2009 to March 2010. NJRES will incur demand fees payable to Steckman Ridge aggregating approximately $5.5 million annually. As of June 30, 2009, NJRES’ fees and related payable balances were immaterial.

17.

OTHER

At June 30, 2009, there were 41,950,253 shares of common stock outstanding and the book value per share was $17.36.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The accompanying Management's Discussion and Analysis of Financial Condition and Results of Operations gives effect to the restatement of the Company's unaudited condensed consolidated statements for the three and nine months ended June 30, 2009 and 2008 and for the condensed consolidated balance sheets as of June 30, 2009 and September 30, 2008, as discussed in Note 2 to the Company's condensed consolidated financial statements in Part I, Item 1.

Management’s Overview

New Jersey Resources Corporation (NJR or the Company) is an energy services holding company consisting of the Natural Gas Distribution segment, Energy Services segment, and Retail and Other operations.

Comprising the Natural Gas Distribution segment, New Jersey Natural Gas (NJNG) is a natural gas utility that provides regulated retail natural gas service in central and northern New Jersey and also participates in the off-system sales and capacity release markets. NJNG is regulated by the New Jersey Board of Public Utilities (BPU).

NJR Energy Services (NJRES) comprises the Energy Services segment. NJRES maintains and transacts around a portfolio of physical assets consisting of natural gas storage and transportation contracts. In addition, NJRES provides wholesale energy services to non-affiliated utility and energy companies.

The retail and other operations (Retail and Other) includes NJR Energy, an investor in energy-related ventures, most significantly through NJNR Pipeline Company, which holds the Company’s 5.53 percent interest in Iroquois Gas and Transmission System, LP (Iroquois), a 412-mile natural gas pipeline from the New York-Canadian border to Long Island, New York, and NJR Steckman Ridge Storage Company, which has a 50 percent equity ownership interest in Steckman Ridge GP, LLC and Steckman Ridge, LP (collectively, Steckman Ridge), a 17.7 billion cubic foot (Bcf) natural gas storage facility, with up to 12 Bcf working capacity, which is being jointly developed, constructed and operated with a partner in Pennsylvania; NJR Investment Company, which makes energy-related equity investments; NJR Home Services Company (NJRHS), which provides service, sales and installation of appliances; Commercial Realty and Resources Corporation (CR&R), which holds and develops commercial real estate; and NJR Service Corporation (NJR Service), which provides support services to the various NJR businesses.

Assets by business segment and business operations are as follows:

(Thousands)	June 30, 2009					September 30, 2008
Assets
Natural Gas Distribution	$	1,745,411		76	%	$	1,761,964		67	%
Energy Services		374,500		16			699,897		26
Retail and Other		215,343		9			231,551		9
Intercompany Assets (1)		(21,955	)	(1	)		(58,115	)	(2	)
Total	$	2,313,299		100	%	$	2,635,297		100	%

(1) Consists of transactions between subsidiaries that are eliminated and reclassified in consolidation

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

NJRES and NJR Energy account for certain of their derivative instruments used to economically hedge the forecasted purchase, sale and transportation of natural gas at fair value, as required under Statement of Financial Accounting Standards No. 133, Accounting for Derivative Instruments and Hedging Activities (as amended and interpreted), (SFAS 133). Effective October 1, 2007, the Company changed the treatment of its physical commodity contracts at NJRES, such that the changes in fair value of new contracts are included in earnings, and are not accounted for using the “normal purchase normal sales” (normal) scope exception of SFAS 133. In addition, effective October 1, 2008, due to changes in the Company’s ability to assert physical delivery, the Company is no longer treating physical commodity contracts executed prior to October 1, 2007 as normal. Therefore, all NJRES physical commodity contracts are accounted for at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in fair value included as a component of operating revenue and gas purchases, as appropriate, on the Unaudited Condensed Consolidated Statements of Income. All physical commodity contracts at NJNG and NJR Energy continue to be designated as normal and accounted for under accrual accounting.

The change in fair value of these derivative instruments at NJRES and NJR Energy over periods of time, referred to as unrealized gains or losses, can result in substantial volatility in reported net income under generally accepted accounting principles of the United States of America (GAAP). When a financial instrument settles the result is the realization of these gains or losses. NJRES utilizes certain financial instruments to economically hedge natural gas inventory placed into storage that will be sold at a later date, all of which were contemplated as part of an entire forecasted transaction. GAAP requires that when a financial instrument that is economically hedging natural gas that has been placed into inventory, but not yet sold, has been settled, the realized gain or loss associated with that settlement must be reflected currently in the income statement. While NJRES will recognize the same economic impact from the entire planned transaction, this also leads to additional volatility in NJRES’ reported earnings.

Unrealized losses and gains at NJRES and NJR Energy are the result of changes in the fair value of derivative instruments, used to economically hedge future natural gas purchases, sales and transportation. Realized gains and losses at NJRES include the settlement of natural gas futures instruments used to economically hedge natural gas purchases in inventory that have not been sold.

Included in Net income for the nine-month period ended June 30, 2009 and 2008, are unrealized (losses) in the Energy Services segment of $(29.3) million and $(108) million, after taxes, respectively and realized (losses) gains of $(20.5) million and $10.4 million, after taxes, respectively, which are related to derivative instruments that have settled and are designed to economically hedge natural gas that is in storage inventory.

Also, included in Net income are unrealized (losses) gains in the Retail and Other operations of $(10.2) million and $10.2 million, after taxes, for the nine-month period ended June 30, 2009 and 2008, respectively.

Natural Gas Distribution Segment

Natural Gas Distribution operations have been managed with the goal of growing profitably through several key initiatives including:

Earning a reasonable rate of return on the investments in its natural gas distribution system, as well as recovery of all prudently incurred costs in order to provide safe and reliable service throughout NJNG’s service territory;

Working with the BPU and the Department of the Public Advocate, Division of Rate Counsel (Rate Counsel), on the implementation and continuing review of the Conservation Incentive Program (CIP). The CIP allows NJNG to promote conservation programs to its customers while maintaining protection of its utility gross margin against potential losses associated with reduced customer usage. CIP usage differences are calculated annually and are recovered one year following the end of the CIP usage year;

Managing the new customer growth rate which is expected to be approximately 1.3 percent over the next two years. In fiscal 2009 and 2010, NJNG currently expects to add, in total, approximately 12,000 to 14,000 new customers. The Company believes that this stable growth would increase utility gross margin under its base rates as provided by approximately $3.6 million annually, as calculated under NJNG’s CIP tariff;

Generating earnings from various BPU-authorized gross margin-sharing incentive programs; and

Managing the volatility of wholesale natural gas prices through a hedging program designed to keep customers’ Basic Gas Supply Service (BGSS) rates as stable as possible.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Based upon increases in NJNG’s operation, maintenance and capital costs, NJNG petitioned the BPU, on November 20, 2007, to increase base rates for its natural gas delivery service. This base rate case filing was consistent with NJNG’s objectives of providing safe and reliable service to its customers and earning a market-based return.

On October 3, 2008, the BPU unanimously approved and made effective the settlement of NJNG’s base rate case. As a result, NJNG received a revenue increase in its base rates of $32.5 million, which is inclusive of an approximate $13 million impact of a change to the CIP baseline usage rate, received an allowed return on equity component of 10.3 percent, reduced its depreciation expense component from 3 percent to 2.34 percent and reduced its annual depreciation expense by $1.6 million as a result of the amortization of previously recovered asset retirement obligations.

The CIP allows NJNG to recover utility gross margin variations related to both weather and customer usage. Recovery of such margin variations is subject to additional conditions including an earnings test, which includes a return on equity component of 10.3 percent, and an evaluation of Basic Gas Supply Service (BGSS)-related savings achieved. An annual review of the CIP must be filed in June of each year, coincident with NJNG’s annual BGSS filing. In October 2007, the BPU provisionally approved NJNG’s initial CIP recovery rates, which are designed to recover approximately $15.6 million of accrued margin and on August 1, 2008, the provisional rates were approved by the BPU on a permanent basis. In October 2008, the BPU provisionally approved recovery of an additional $6.8 million of accrued margin for the CIP, resulting in a total recovery requested of $22.4 million includes amounts accrued and estimated through September 30, 2008. On June 10, 2009, these provisional rates were approved by the BPU on a permanent basis. On June 1, 2009, NJNG filed its annual BGSS and CIP filing for recoverable CIP amounts for fiscal 2009, requesting approval to modify its CIP recovery rates effective October 1, 2009, resulting in total annual recovery of $6.9 million. The total recovery requested for fiscal 2009 includes amounts accrued and estimated through September 30, 2009. As of June 30, 2009, NJNG has $6.3 million accrued to be recovered in Regulatory Assets in the Unaudited Condensed Consolidated Balance Sheets. On April 1, 2009, NJNG filed a letter with the BPU requesting a 1-year extension to its CIP through October 1, 2010.

In conjunction with the CIP, NJNG is required to administer programs that promote customer conservation efforts. As of June 30, 2009 and September 30, 2008, the obligation to fund these conservation programs was reflected at its present value of $269,000 and $864,000, respectively in the Unaudited Condensed Consolidated Balance Sheets.

In conducting NJNG’s business, management focuses on factors it believes may have significant influence on its future financial results. NJNG’s policy is to work with all stakeholders, including customers, regulators and policymakers, to achieve favorable results. These factors include the rate of NJNG’s customer growth in its service territory, which can be influenced by general economic conditions as well as political and regulatory policies that may impact the new housing market. A portion of NJNG’s customer growth comes from the conversion market, which is influenced by the delivered cost of natural gas compared with competing fuels, interest rates and other economic conditions.

As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. As a result, significant costs are deferred and treated as regulatory assets, pending BPU decisions regarding their ultimate recovery from customers. The most significant costs incurred that are subject to this accounting treatment include manufactured gas plant (MGP) remediation costs and wholesale natural gas costs. Actual remediation costs may vary from management’s estimates due to the developing nature of remediation requirements, regulatory decisions by the New Jersey Department of Environmental Protection (NJDEP) and related litigation. If there are changes in the regulatory position on the recovery of these costs, such costs would be charged to income in the period of such determination.

On April 16, 2009, the BPU approved NJNG’s AIP allowing NJNG to commence construction on 14 infrastructure projects. NJNG will make a filing for the recovery of infrastructure program investment costs in June 2010 to be effective October 1, 2010. The filing will allow the recovery of costs of the AIP construction activities for the period ending August 31, 2010, including the recovery of NJNG’s overall weighted cost of capital on these investments.

On July 1, 2009, the BPU approved NJNG’s Energy Efficiency (EE) Program allowing approximately $21.1 million, if fully subscribed, to support three EE Programs. A Tariff Rider Mechanism was approved by the BPU related to the recovery of the EE Program costs, effective August 1, 2009, and includes the recovery of NJNG’s overall weighted cost of capital on these investments.

Due to the capital-intensive nature of NJNG’s operations and the seasonal nature of its working capital requirements, significant changes in interest rates can also impact NJNG’s results.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Energy Services Segment

NJRES provides unregulated wholesale energy services and engages in the business of optimizing natural gas storage and transportation assets. The rights to these assets are contractually acquired in anticipation of delivering natural gas or performing asset management activities for our customers or in conjunction with identifying arbitrage opportunities that exist in the marketplace. These arbitrage opportunities occur as a result of price differences between market locations and/or time horizons. These activities are conducted in the market areas in which we have expertise and include states from the Gulf Coast and Mid-continent regions to the Appalachian and Northeast regions and Canada.

More specifically, NJRES activities consist of the following elements which provide for growth, while focusing on maintaining a low-risk operating and counterparty credit profile:

Identifying and benefiting from variations in pricing of natural gas transportation and storage assets due to location or timing differences of natural gas prices to generate gross margin;

Providing natural gas portfolio management services to nonaffiliated utilities and electric generation facilities;

Leveraging transactions for the delivery of natural gas to customers by aggregating the natural gas commodity costs and transportation costs in order to minimize the total cost required to provide and deliver natural gas to NJRES’ customers by identifying the lowest cost alternative with the natural gas supply, transportation availability and markets to which NJRES is able to access through its business footprint and contractual asset portfolio; and

Managing economic hedging programs that are designed to mitigate adverse market price fluctuations in natural gas transportation and storage commitments.

NJRES views “financial margin” as a financial measurement metric. NJRES’ financial margin, which is a non-GAAP financial measure, represents revenues earned from the sale of natural gas less costs of natural gas sold, transportation and storage, and excludes any accounting impact from the change in fair value of derivative instruments designed to hedge the economic impact of its transactions that have not been settled, which represent unrealized gains and losses, and realized gains and losses associated with financial instruments economically hedging natural gas in storage and not yet sold as part of a planned transaction. NJRES uses financial margin to gauge operating results against established benchmarks and earnings targets as it eliminates the impact of volatility in GAAP earnings that can occur prior to settlement of the physical commodity portion of the transactions and therefore is more representative of the overall expected economic result.

NJRES focuses on creating value from underutilized natural gas assets, which are typically amassed through contractual rights to natural gas transportation and storage capacity. NJRES has developed a portfolio of natural gas storage and transportation capacity in states in the Northeast, Gulf Coast, Mid-continent and Appalachian regions of the United States and eastern Canada. These assets become more valuable when prices change between these areas and across time periods. NJRES is able to capture financial margin by locking in the differential between purchasing natural gas at a low future price and, in a related transaction, selling that natural gas at a higher future price, all within the constraints of its credit and contracts policies. In addition, NJRES seeks to optimize on a daily basis as market conditions change by evaluating all the natural gas supplies, transportation and opportunities to which it has access, to find the most profitable alternative to serve its various commitments. This enables NJRES to capture geographic pricing differences across these various regions as delivered natural gas prices change as a result of market conditions. NJRES focuses on earning a financial margin on a single original transaction and then utilizing that transaction, and the changes in prices across the regions or across time periods, as the basis to further improve the initial result.

NJRES transacts with a variety of counterparties including local distribution companies, industrial companies, electric generators and retail aggregators. The physical sales commitments to these counterparties allows NJRES to leverage its transportation and storage capacity. These physical sale commitments are managed in an aggregate fashion, and as a result, gives NJRES the ability to extract more value from its portfolio of natural gas storage and pipeline transportation capacity. NJRES’ portfolio management customers include nonaffiliated utilities and electric generation plants. Services provided by NJRES include optimization of underutilized natural gas assets and basic gas supply functions.

In conducting its business, NJRES utilizes risk management practices which include a formal risk management policy that includes trading limits, approval processes, segregation of duties, and formal contract and credit review and approval procedures. NJRES continuously monitors and seeks to reduce the risk associated with various counterparties credit exposure. The Risk Management Committee (RMC) of NJR oversees compliance with these established guidelines.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Retail and Other Operations

As part of the Retail and Other operations NJR utilizes a subsidiary, NJR Energy Holdings, to develop its investments in natural gas “mid-stream” assets. Mid-stream assets are natural gas transportation and storage facilities. NJR believes that acquiring, owning and developing these mid-stream assets, which operate under a tariff structure that has either a regulated or market-based rate, can provide a significant growth opportunity for the Company. To that end, NJR has ownership interests in Iroquois (regulated rate) and Steckman Ridge (market-based rate), and is actively pursuing other potential opportunities that meet its investment and development criteria. Other businesses included as part of Retail and Other include NJRHS, which provides service, sales and installation of appliances to over 148,000 customers and is focused on growing its installation business and expanding its service contract customer base, and CR&R, which seeks additional opportunities to enhance the value of its undeveloped land.

The financial results of Retail and Other consist primarily of the operating results of NJRHS and equity in earnings attributable to the Company’s equity investment in Iroquois, as well as to investments made by NJR Energy, an investor in other energy-related ventures through its operating subsidiaries. Also included within Retail and Other operations are interest income and organizational expenses incurred at NJR.

On June 5, 2008, the Federal Energy Regulatory Commission (FERC) issued Steckman Ridge a certificate of public convenience and necessity authorizing the ownership, construction and operation of its natural gas storage facility and associated facilities. On April 1, 2009, Steckman Ridge received authorization to place certain injection related facilities into commercial operation. Customers have begun to inject natural gas inventory in preparation for the initial withdrawal season. Construction will continue through the summer of 2009 as more facilities are made ready to support the initial winter season. As of June 30, 2009, NJR had invested $120 million in Steckman Ridge, excluding capitalized interest and other direct costs. Total project costs related to the development of the storage facility are currently estimated at approximately $265 million, of which NJR is obligated to fund 50 percent or approximately $132.5 million. NJR anticipates that Steckman Ridge could seek non-recourse financing upon full completion of the construction and development of its facilities, thereby potentially reducing the final expected recourse obligation of NJR. There can be no assurances that such non-recourse project financing will be secured or available for Steckman Ridge.

Critical Accounting Policies

A summary of NJR’s critical accounting policies is included in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of its Annual Report on Form 10-K for the period ended September 30, 2008. NJR’s critical accounting policies have not changed materially from those reported in the 2008 Annual Report on Form 10-K with the exception of the following:

Derivative Instruments

Derivative activities are recorded in accordance with SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities, as amended and interpreted, (SFAS 133) under which NJR records the fair value of derivatives held as assets and liabilities. In addition, NJRES also treats contracts for the purchase or sale of natural gas as derivatives and, therefore, records them at fair value in the Unaudited Condensed Consolidated Balance Sheet, with changes in fair value being recorded as a component of Gas purchases in the Unaudited Condensed Consolidated Statements of Income.

NJRES previously applied the “normal purchase normal sale” (normal) scope exception for certain physical commodity contracts that were executed prior to October 1, 2007 which otherwise qualified as derivatives. Based on current conditions in the credit markets and developments within the natural gas industry, NJRES has determined that the probability of physical delivery with these counterparties could potentially diminish and, therefore, these contracts do not meet the requirements, outlined in SFAS 133, to continue applying the normal scope exception. As a result, effective October 1, 2008, NJRES began treating these contracts as derivatives and record them at fair value in the Unaudited Condensed Consolidated Balance Sheet, with changes in fair value being recorded as a component of Operating revenues and Gas purchases, as appropriate, in the Unaudited Condensed Consolidated Statements of Income.

Effective October 1, 2008, NJR began applying the provisions of SFAS 157 Fair Value Measurement (see Note 5, Fair Value). As a result of the adoption of SFAS 157, NJR implemented procedures to evaluate its own credit profile to determine an appropriate valuation adjustment to the recorded amount of its derivative liabilities. NJR uses historical default probabilities corresponding to Standard and Poor’s issuer ratings.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Capitalized Financing Costs

NJNG capitalizes an allowance for funds used during construction (AFUDC) as a component of Utility plant in the Unaudited Condensed Consolidated Balance Sheets. Under regulatory rate practices and in accordance with SFAS No. 71, Accounting for the Effects of Certain Types of Regulation, NJNG fully recovers AFUDC through base rates. As a result of the BPU’s Base Rate order issued in October 2008, NJNG implemented certain rate design changes, including a change to its AFUDC calculation. Effective October 3, 2008, NJNG is allowed to recover an incremental cost of equity component during periods when its short-term debt balances are lower than its construction work in progress balance. This results in a non-cash income statement recognition that will also be capitalized as a component of Utility plant.

Foreign Currency Transactions

NJRES’ market area includes Canadian delivery points and as a result it incurs certain natural gas commodity costs and demand fees that are denominated in Canadian dollars. Gains or losses that occur as a result of these foreign currency transactions are reported as a component of Gas purchases in the Consolidated Statements of Income and were not material during the three and nine months ended June 30, 2009 and June 30, 2008, respectively.

Recently Issued Accounting Standards

Refer to Note 1. General, for discussion of recently issued accounting standards.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Results of Operations

Our business segments and operations contributed the following to consolidated net income for the three and nine months ended June 30, 2009 and 2008:

	Three Months Ended										Nine Months Ended
	June 30,										June 30,
(Thousands)	2009					2008					2009					2008
Net income (loss)
Natural Gas Distribution	$	4,134		(29	)%	$	147		(1	)%	$	68,796		149	%	$	50,987		223	%
Energy Services		(20,170	)	142			(32,878	)	132			(13,828	)	(30	)		(40,646	)	(178	)
Retail and Other		1,881		(13	)		7,802		(31	)		(8,863	)	(19	)		12,479		55
Total	$	(14,155	)	100	%	$	(24,929	)	100	%	$	46,105		100	%	$	22,820		100	%

Net (loss) for the three-month period ended June 30, 2009, decreased by 43 percent to $(14.2) million, compared with $(24.9) million for the same period last fiscal year. Basic and diluted loss per share decreased 43 percent to $(0.34) compared with $(0.59) for the same period last fiscal year. The decrease in net loss during the three months ended June 30, 2009, was due primarily to a change in the value of storage inventory and derivative contracts at NJRES and lower unrealized losses at Retail and Other as a result of a continuing decline in natural gas commodity prices. Partially offsetting these losses was an increase in margins at NJNG, as a result of the BPU approved increase in its base rates that took effect at the beginning of fiscal 2009.

Net income for the nine-month period ended June 30, 2009, increased 102 percent to $46.1 million, compared with $22.8 million for the same period last fiscal year. Basic and diluted EPS increased 98.2 percent to $1.09, compared with $0.55 and 100 percent to $1.08, compared with $0.54, respectively, for the same period last fiscal year. The decrease in net income was primarily due to unrealized losses at Retail and Other as a result of the impact of lower commodity prices on long financial derivative contracts, which was partially offset by improved margins at NJNG as a result of the changes to its base rates and higher gross margin from incentive programs and an overall reduction in interest expense driven by lower average debt balances and short-term borrowing rates.

The Company’s Operating revenues and Gas purchases are as follows:

	Three Months Ended June 30,							Nine Months Ended June 30,
(Thousands)	2009		2008		% Change			2009		2008		% Change
Operating revenues	$	441,052	$	1,000,439		(55.9	)%	$	2,179,872	$	2,989,122		(27.1	)%
Gas purchases	$	400,487	$	974,677		(58.9	)%		1,859,495		2,716,761		(31.6	)%

Operating revenues decreased $559.4 million and Gas purchases decreased $574.2 million in the three months ended June 30, 2009, compared with the same period of the prior fiscal year due primarily to:

a decrease in Operating revenues of $518.2 million and Gas purchases of $537.9 million at NJRES due primarily to lower average natural gas prices, which correlate to the decrease in NYMEX prices of 70 percent from an average of $11.49 to $3.81;

a decrease in Operating revenues of $30.7 million and Gas purchases of $37.9 million at NJNG due primarily to a 67 percent decrease in off-system sales prices from an average of $11.85/dth to $3.87/dth; and

a decrease in Operating revenues of $10.5 million at Retail and Other due to an increase of $10.4 million in unrealized losses at NJR Energy, which were the result of declining natural gas market prices within a portfolio of net long financial derivative positions.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

For the nine months ended June 30, 2009, Operating revenues decreased $809.3 million and Gas purchases decreased $857.3 compared with the same period of the prior fiscal year due primarily to:

a decrease in Operating revenues of $790.5 million and Gas purchases of $837 million at NJRES due primarily to the same factors noted above;

a decrease in Operating revenues of $35 million at Retail and Other due to an increase of $34.7 million of unrealized losses at NJR Energy due primarily to the same factors noted above; partially offset by

an increase in Operating revenues of $18.3 million and a decrease in Gas purchases of $21.5 million at NJNG. The increase in Operating revenue was due primarily to an increase in firm sales as a result of colder weather during the current fiscal period, partially offset by higher credits extended to customers during fiscal 2009, in comparison to the BGSS refunds given to customers during fiscal 2008. In addition, operating revenues were favorably impacted by the base rate increase, while increased credits from incentive programs contributed to the decrease in Gas purchases.

Natural Gas Distribution Operations

NJNG is a local natural gas distribution company that provides regulated retail energy services to approximately 487,000 residential and commercial customers in central and northern New Jersey and participates in the off-system sales and capacity release markets.

NJNG’s business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered. Specifically, customer demand substantially increases during the winter months when natural gas is used for heating purposes. As a result, NJNG receives most of its gas distribution revenues during the first and second fiscal quarters and is subject to variations in earnings and working capital during the year.

The Electric Discount and Energy Competition Act (EDECA) provides the framework for New Jersey’s energy markets, which are open to competition from other energy suppliers. Currently, NJNG’s residential markets are open to competition, and its rates are segregated between BGSS (natural gas commodity) and delivery (i.e., transportation) components. NJNG earns no utility gross margin on the commodity portion of its natural gas sales. NJNG earns utility gross margin through the delivery of natural gas to its customers. Under an existing order from the BPU, BGSS can be provided by suppliers other than the state’s natural gas utilities.

NJNG’s unaudited financial results are as follows:

	Three Months Ended June 30,					Nine Months Ended June 30,
(Thousands)	2009		2008			2009		2008
Utility Gross Margin
Operating revenues	$	148,826	$	179,511		$	958,995	$	940,689
Less:
Gas purchases		87,169		125,060			631,712		653,196
Energy and other taxes		9,830		9,031			61,208		53,137
Regulatory rider expense		6,280		5,925			40,585		35,879
Total Utility Gross Margin		45,547		39,495			225,490		198,477
Operation and maintenance expense		27,351		21,637			79,137		69,417
Depreciation and amortization		7,668		9,488			22,120		28,053
Other taxes not reflected in utility gross margin		819		818			2,807		2,642
Operating Income		9,709		7,552			121,426		98,365
Other income		822		(41	)		2,534		2,641
Interest charges, net of capitalized interest		4,028		4,146			14,692		15,641
Income tax provision		2,369		3,218			40,472		34,378
Net Income	$	4,134	$	147		$	68,796	$	50,987

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

The following table summarizes Utility Gross Margin and throughput in billion cubic feet (Bcf) of natural gas by type:

	Three Months Ended								Nine Months Ended
	June 30,								June 30,
	2009				2008				2009				2008
($ in thousands)	Margin		Bcf		Margin		Bcf		Margin		Bcf		Margin			Bcf
Residential	$	28,488		5.8	$	26,080		5.6	$	150,235		40.5	$	137,667			37.8
Commercial, Industrial & Other		9,051		1.2		7,455		1.3		40,398		9.1		40,478			8.3
Transportation		5,987		1.5		4,639		1.4		24,838		8.4		15,438			8.0
Total Utility Firm Gross Margin		43,526		8.5		38,174		8.3		215,471		58.0		193,583			54.1
Incentive programs		1,940		13.6		1,225		5.6		9,783		45.9		4,836			26.8
Interruptible		81		1.0		96		1.6		236		2.6		358			4.2
BPU settlement		—		—		—		—		—		—		(300	)		—
Total Utility Gross Margin/throughput	$	45,547		23.1	$	39,495		15.5	$	225,490		106.5	$	198,477			85.1

Utility Gross Margin

NJNG’s utility gross margin is defined as natural gas revenues less natural gas purchases, sales tax, a Transitional Energy Facilities Assessment (TEFA) and regulatory rider expenses, and may not be comparable to the definition of gross margin used by others in the natural gas distribution business and other industries. Utility gross margin is comprised of three major categories which include utility firm gross margin, incentive programs and utility gross margin from interruptible customers. Management believes that utility gross margin provides a more meaningful basis than revenue for evaluating utility operations since natural gas costs, sales tax, TEFA and regulatory rider expenses are included in operating revenue and passed through to customers and, therefore, have no effect on utility gross margin.

Natural gas costs are charged to operating expenses on the basis of therm sales at the prices in NJNG’s BGSS tariff approved by the BPU. The BGSS tariff rate includes projected natural gas costs, net of supplier refunds, the impact of hedging activities and credits from non-firm sales and transportation activities. Any underrecoveries or overrecoveries from the projected amounts are deferred and reflected in the BGSS tariff rate in subsequent years.

TEFA, which is included in Energy and other taxes on the Unaudited Condensed Consolidated Statements of Income, is calculated on a per-therm basis and excludes sales to cogeneration facilities, other utilities and off-system sales. TEFA represents a regulatory allowed assessment imposed on all energy providers in the state of New Jersey, as TEFA has replaced the previously used utility gross receipts tax formula.

Regulatory rider expenses consist of recovery of state-mandated programs and the remediation adjustment clause costs. These expenses are offset by corresponding revenues and are calculated on a per-therm basis.

NJNG’s Operating revenues decreased by $30.7 million, or 17.1 percent, and Gas purchases decreased by $37.9 million, or 30.3 percent, for the three months ended June 30, 2009, respectively, compared with same period in the prior fiscal year as a result of:

a decrease in Operating revenue and Gas purchases related to off-system sales in the amount of $34.7 million and $34.6 million, respectively, as a result of 67 percent lower average sale prices from $11.85/dth compared with $3.87/dth due to the change in the wholesale price of natural gas; and

a decrease in Operating revenue and Gas purchases related to interruptible sales in the amount of $1.9 million and $1.6 million, respectively, due to a decrease in sales to electric co-generation customers; partially offset by

an increase in Operating revenue and Gas purchases related to total firm sales in the amount of $9.6 million and $1.4 million, respectively, as a result of an increase in BGSS, base rates and rates associated with riders.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

NJNG’s Operating revenues increased by $18.3 million, or 1.9 percent, and Gas purchases decreased by $21.5 million, or 3.3 percent, for the nine months ended June 30, 2009, respectively, compared with the same period in the prior fiscal year as a result of:

an increase in Operating revenue related to firm sales in the amount of $76.1 million, as a result of increases in BGSS, base rates, rates associated with riders and sales tax and TEFA as described below and an increase in Gas purchases in the amount of $40.1 million, as a result of the BGSS increases;

an increase in Operating revenue and Gas purchases related to firm sales in the amount of $51.2 million and $34.1 million, respectively, due primarily to weather being 8.6 percent colder than the same period of the prior fiscal year, partially offset by a decrease in Operating revenue of $18.8 million, as a result of lower accruals relating to the CIP during the current fiscal period;

a decrease in Operating revenue and Gas purchases related to off-system sales in the amount of $66.8 million and $67.4 million, respectively, as a result of a 41.9 percent lower average sales prices that decreased from $10.05/dth to $5.84/dth due to the change in the wholesale price of natural gas;

a net decrease in Operating revenue and Gas purchases of $15 million related to fiscal 2009 temporary rate credits of approximately $45 million extended to customers, compared with a BGSS refund of $30 million given to customers during fiscal 2008. NJNG extends these credits and refunds to its customers to manage the recovery of its gas costs during periods when wholesale natural gas costs are declining in comparison with the established rate included in NJNG’s BGSS tariff;

a decrease of $5.2 million in Gas purchases related to increased amounts received through the storage incentive program due primarily to the timing of the incentive margins during the program's injection period as compared with the same period in the prior fiscal year;

a decrease in Operating revenue and Gas purchases related to interruptible sales in the amount of $4.6 million and $4 million, respectively, due to a decrease in sales to electric co-generation customers; and

a decrease of $2.6 million in Gas purchases related to increased amounts earned through the financial risk management (FRM) and capacity release incentive programs of $3.2 million in fiscal 2009 as compared with $559,000 in fiscal 2008 due primarily to lower NYMEX market prices in comparison to published benchmark prices, resulting in additional opportunities to purchase call options that were below the established quarterly Financial Risk Management (FRM) benchmark pricing levels.

Sales tax and TEFA, which are presented as both components of Revenues and Operating Expenses in the Unaudited Condensed Consolidated Statements of Income, totaled $9.8 million and $9 million for the three months ended June 30, 2009 and 2008, respectively. For the nine months ended June 30, 2009 and 2008, Sales tax and TEFA totaled $61.2 million and $53.1 million, respectively. The increase for both periods was due primarily to an increase of operating revenue from firm sales of $17.7 million and $113.4 million for the three and nine months ended June 30, 2009, respectively.

Regulatory rider expenses are calculated on a per-therm basis and totaled $6.3 million and $5.9 million for the three month periods ended June 30, 2009 and 2008, respectively, and $40.6 million and $35.9 million for the nine month periods ended June 30, 2009 and 2008, respectively. The increase was due primarily to an increase in firm throughput of 0.2 Bcf for the three months and 3.9 Bcf for the nine months ended June 30, 2009, as compared with the three and nine months ended June 30, 2008, respectively, as a result of the previously mentioned colder weather coupled with an increase in the SBC rate.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Utility gross margin is comprised of three major categories:

Utility firm gross margin, which is derived from residential and commercial customers who receive natural gas service from NJNG through either sales or transportation tariffs;

Incentive programs, where margins generated or savings achieved from BPU-approved off-system sales, capacity release, Financial Risk Management (defined in Incentive Programs, below) or storage incentive programs are shared between customers and NJNG; and

Utility gross margin from interruptible customers who have the ability to switch to alternative fuels.

Utility Firm Gross Margin

Utility firm gross margin is earned from residential and commercial customers who receive natural gas service from NJNG through either sales or transportation tariffs.

As a result of NJNG’s implementation of the CIP, utility gross margin is no longer linked to customer usage. The CIP eliminates the disincentive to promote conservation and energy efficiency and facilitate normalizing NJNG’s utility gross margin recoveries for variances not only in weather but also in other factors affecting usage, including customer conservation. Recovery of utility gross margin for the non-weather variance through the CIP is limited to the amount of certain gas supply cost savings achieved and is subject to an earnings test, which contains a return on equity component of 10.3 percent.

NJNG’s total utility gross margin is not negatively affected by customers who use its transportation service and purchase natural gas from another supplier because its tariff is designed so that no profit is earned on the commodity portion of sales to firm customers. All customers who purchase natural gas from another supplier continue to use NJNG for transportation service.

Total utility firm gross margin increased $5.4 million, or 14 percent, and $21.9 million, or 11.3 percent, for the three and nine months ended June 30, 2009, respectively, as compared with the same periods in the prior fiscal year, due primarily to an increase in residential and commercial transport customer margin as a result of an increase in base rates effective October 3, 2008, partially offset by a decrease in the amounts accrued through the CIP program. Firm margin was also favorably impacted by the increase in firm and transport customers of 1,300 and 3,000, respectively, over the same periods in the prior fiscal year.

Utility firm gross margin from residential service sales increased to $28.5 million and $150.2 million for the three and nine months ended June 30, 2009, respectively, as compared with $26.1 million and $137.7 million for the three and nine months ended June 30, 2008, respectively. NJNG delivered 5.8 Bcf compared with 5.6 Bcf, to its firm residential customers, in the three months ended June 30, 2009 and 2008, respectively. In the nine months ended June 30, 2009, NJNG delivered 40.5 Bcf compared with 37.8 Bcf during the same period in fiscal 2008 due primarily to weather being 8.6 percent colder.

Utility firm gross margin from transportation service increased to $6 million and $24.8 million for the three and nine months ended June 30, 2009, respectively, as compared with $4.6 million and $15.4 million for the three and nine months ended June 30, 2008, respectively. NJNG delivered 1.5 Bcf and 8.4 Bcf for the three and nine months ended June 30, 2008, respectively, to its customers that utilize its transportation service, compared with 1.4 Bcf and 8 Bcf, respectively, for the same periods ended June 30, 2008. The increase for both periods was due primarily to the change in base rates, effective in October 2008.

The weather for both the three months ended June 30, 2009 and 2008, was 15.6 percent warmer-than-normal, based on a 20-year average, which resulted in a positive adjustment of utility gross margin under the weather component of the CIP of $1.9 million and $1.7 million, respectively. The weather for the nine months ended June 30, 2009, was 1 percent colder-than-normal, which resulted in a negative adjustment of $(177,000), compared with 8.3 percent warmer-than-normal weather for the same period last fiscal year, which resulted in an accrual of utility gross margin of $9.1 million. Under the provisions of the CIP, accruals related to the weather portion are dependent on the occurrence of degree days and the magnitude of the variance in relation to the normal number of degree days.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Customer usage was higher than the established benchmark during the three months ended June 30, 2009, which resulted in an adjustment of utility gross margin under the CIP of $(189,000), compared with an accrual of $2.7 million, during the three months ended June 30, 2008. Customer usage was lower than the established benchmark during the nine months ended June 30, 2009, which resulted in an accrual of utility gross margin under the CIP of $2.2 million, compared with $11.5 million, during the three months ended June 30, 2008. The change in the weather and non-weather components of the CIP include the effect of adjustments, normal degree days, consumption factors and benchmarks related to the baseline use per customer, which was amended with NJNG’s new base rates approved by the BPU effective October 3, 2008.

NJNG had 13,213 and 10,697 residential customers and 5,679 and 5,179 commercial customers using its transportation service at June 30, 2009 and 2008, respectively. The increase in transportation customers for the nine month period ended June 30, 2009, was due primarily to an increase in marketing activity by third party natural gas providers in NJNG’s distribution territory.

NJNG added 4,193 and 4,896 new customers during the nine months ended June 30, 2009 and 2008, respectively. In addition, NJNG converted 460 and 505 existing customers to natural gas heat and other services during the same periods for fiscal 2009 and 2008, respectively. The decline in customer growth is driven by a slower new construction market. This customer growth represents an estimated annual increase of approximately 0.78 Bcf in sales to firm customers, assuming normal weather and usage which would contribute approximately $2.5 million to utility gross margin.

Incentive Programs

To reduce the overall cost of its natural gas supply commitments, NJNG has entered into contracts to sell natural gas to wholesale customers outside its franchise territory when the natural gas is not needed for system requirements. These off-system sales enable NJNG to reduce its overall costs applicable to BGSS customers. NJNG also participates in the capacity release market on the interstate pipeline network when the capacity is not needed for its firm system requirements. NJNG retains 15 percent of the utility gross margin from these sales, with 85 percent credited to firm customers through the BGSS.

The Financial Risk Management (FRM) program is designed to provide price stability to NJNG’s natural gas supply portfolio. The FRM program includes an incentive mechanism designed to encourage the use of financial instruments to economically hedge NJNG’s natural gas costs. Gross margin is generated by entering into financial option positions that have a strike price below a published quarterly benchmark, minus premiums and associated fees. NJNG retains 15 percent of the utility gross margin, with 85 percent credited to firm customers through the BGSS.

The storage incentive program shares gains and losses on an 80 percent and 20 percent basis between customers and NJNG, respectively. This program measures the difference between the actual cost of natural gas injected into storage and a benchmark established with the purchase of a portfolio of futures contracts applicable to the April-through-October natural gas injection season.

On October 3, 2008, the BPU issued the Base Rate order, which extends the incentive programs through October 31, 2011, and provides changes to certain volume and cost limitations surrounding these incentive programs.

Sales under NJNG’s incentive programs totaled 13.6 Bcf and generated $1.9 million of utility gross margin for the three months ended June 30, 2009, compared with 5.6 Bcf and $1.2 million of utility gross margin during the same period last fiscal year. Sales under the incentive programs totaled 45.9 Bcf and generated $9.8 million of utility gross margin for the nine months ended June 30, 2009, compared with 26.8 Bcf and $4.8 million of utility gross margin during the same period last fiscal year. Utility gross margin from incentive programs comprised 4.3 percent of total utility gross margin for both the three and nine months ended June 30, 2009, and 3.1 percent and 2.4 percent of total utility gross margin for the three and nine months ended June 30, 2008, respectively. The increase in utility gross margin was due primarily to increased amounts earned through the FRM program of $1.6 million for the nine months ended June 30, 2009, and $312,000 and $1.7 million for both the three and nine months ended June 30, 2009, respectively, from increased amounts received through the storage incentive program as discussed above. The increase in FRM is due primarily to NYMEX market prices in the current fiscal year period being consistently lower than the published FRM benchmark prices, resulting in additional opportunities to transact long call options that are below the established quarterly FRM benchmark pricing levels.

Table of Contents

New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Interruptible Revenues

As of June 30, 2009, NJNG serves 61 customers through interruptible transportation and sales services. Interruptible customers are those customers whose service can be temporarily halted as they have the ability to utilize an alternate fuel source. Although therms transported and sold to interruptible customers represented 1 Bcf, or 4.3 percent, and 2.6 Bcf, or 2.4 percent, of total throughput for the three and nine months ended June 30, 2009, respectively, and 1.6 Bcf, or 10.3 percent, and 4.2 Bcf, or 4.9 percent, of the total throughput during the same period in the prior fiscal year, respectively, they accounted for less than 1 percent of the total utility gross margin in each year.

Operation and Maintenance Expense

Operation and maintenance expense increased $5.7 million, or 26.4 percent, during the three months ended June 30, 2009, as compared with the same period in the last fiscal year, due primarily to:

increased benefit costs in the amount of $1.9 million primarily as a result of the decline in equity markets and the related impact on plan asset values;

increased labor costs of $1.3 million due primarily to annual wage increases, partially offset by lower overtime;

higher pipeline integrity costs of $846,000;

an increase in bad debt expense of $650,000 due primarily to additional write-offs as a result of the economic recession; and

an increase in computer software leasing and maintenance of $429,000.

Operation and maintenance expense increased $9.7 million, or 14 percent, during the nine months ended June 30, 2009, as compared with the same period in the last fiscal year, due primarily to:

increased benefit costs of $2.7 million including higher costs associated with postemployment benefits as described above;

increased labor costs of $2 million due to the same factors as above;

an increase in the bad debt expense of $1.9 million associated with higher operating revenues and write-off activity;

higher pipeline integrity costs of $1.1 million;

an increase of $412,000 in contractors expenses due to third party damage repair and increased maintenance; and

increased legal fees of $305,000.

Operating Income

Operating income increased $2.2 million, or 28.6 percent, for the three months ended June 30, 2009, as compared with the same period in the last fiscal year, due primarily to:

an increase in total Utility gross margin of $6.1 million, as discussed above;

a decrease in depreciation expense of $1.8 million, due to a rate reduction from 3 percent to 2.34 percent and amortization of previously recovered asset retirement obligations, both of which were part of the settlement of the base rate case; partially offset by

an increase in Operations and maintenance expense in the amount of $5.7 million, as discussed above.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Operating income increased $23.1 million, or 23.4 percent, for the nine months ended June 30, 2009, as compared with the same period in the last fiscal year, due primarily to:

an increase in total Utility gross margin of $27 million, as discussed above;

a decrease in depreciation expense of $5.9 million, as discussed above;

an increase in interest income of $585,000, due primarily to a settlement of a counterparty receivable that included interest income on escrowed amounts; and

an increase in Operations and maintenance expense in the amount of $9.7 million, as discussed above.

Interest Expense

Interest expense decreased $118,000 and $949,000 for the three and nine months ended June 30, 2009, respectively compared with the same periods in the last fiscal year, due primarily to:

lower average interest rates and balances related to NJNG’s commercial paper program, as well as lower rates associated with its variable rate EDA bonds; partially offset by

the issuance of long-term fixed rate debt of $125 million in May 2008, partially offset by the redemption of a $30 million bond on November 1, 2008.

Net Income

Net income increased $4 million, to $4.1 million in the three months ended June 30, 2009, due primarily to an increase in Operating income of approximately $2.2 million, as discussed above, lower income tax expense of $849,000 and higher Other income of $863,000 due to an aggregate change in the computation of AFUDC Equity interest income in June of fiscal 2008. Net income increased $17.8 million, or 34.9 percent, to $68.8 million in the nine months ended June 30, 2009, due primarily to an increase in Operating income of approximately $23.1 million and lower Interest expense of $949,000, as discussed above, partially offset by higher income tax expense of $6.1 million, as a result of the higher pre-tax income.

Energy Services Operations

NJRES is a non-regulated natural gas marketer principally engaged in the optimization of natural gas storage and transportation assets ultimately resulting in physical delivery of natural gas to its customers, while managing its exposure to the price risk associated with its natural gas commodity supply through the use of financial derivative contracts. NJRES has physical storage and transportation capacity contracts with natural gas storage facilities and pipelines which allow it to take advantage of the continuous changes in supply and demand that it faces in the market areas in which it participates and also assist natural gas marketers, local distribution companies, industrial companies, electric generators and retail aggregators in managing their supply needs. NJRES purchases natural gas predominately in the eastern United States and Canada, and transports that natural gas, through the use of its pipeline contracts to which it has reserved capacity through the payment of a fixed demand charge, to either storage facilities that it has reserved, primarily in the Appalachian, Mid-Continent and Gulf regions of the United States and eastern Canada or directly to customers in various market areas including the Northeastern region of the United States and eastern Canada.

When NJRES enters into contracts for the future delivery and sales of physical natural gas, it simultaneously enters into financial derivative contracts at market prices to establish an initial financial margin for each of its forecasted physical commodity transactions. The financial derivative contracts also serve to protect the cash flows of the transaction from volatility in commodity prices as NJRES locks in pricing and can include futures, options, and swap contracts, which are all predominantly actively quoted on the NYMEX.

Through the use of its contracts for natural gas storage and pipeline capacity, NJRES is able to take advantage of pricing differences between geographic locations, commonly referred to as “locational spreads,” as well as over different time periods, for the delivery of natural gas to its customers, thereby improving the initially established financial margin result. NJRES utilizes financial futures, forwards and swap contracts to establish economic hedges that fix and protect the cash flows surrounding these transactions.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Accordingly, NJRES utilizes these contractual assets to optimize its opportunities to increase its financial margin by capitalizing on changes or events in the marketplace that impact natural gas demand levels. NJRES generates financial margin through three primary channels:

Storage: NJRES attempts to take advantage of differences in market prices occurring over different time periods (time spreads) as follows:

NJRES can purchase gas to inject into storage and concurrently lock in gross margin with a contract to sell the natural gas at a higher price at a future date; and

NJRES can purchase a future contract with an early delivery date at a lower price and simultaneously sell another future contract with a later delivery date having a higher price.

Transportation (Basis): Similarly, NJRES benefits from pricing differences between various receipt and delivery points along a natural gas pipeline as follows:

NJRES can utilize its pipeline capacity by purchasing natural gas at a lower price location and transporting to a higher value location. NJRES can enter into a basis swap contract, a financial commodity derivative based on the price of natural gas at two different locations, when it will lead to positive cash flows and financial margin for NJRES.

Daily Sales Optimization (Cash): Consists of buying and selling flowing gas on a daily basis while optimizing existing transport positions during short-term market price movements to benefit from locational spreads:

Involves increasing the financial margin on established transportation hedges by capitalizing on price movements between specific locations.

Typically, periods of greater price volatility provide NJRES with additional opportunities to generate financial margin by optimizing its storage and transport capacity assets, and capturing their respective time or locational spreads. The combination of strategically positioned natural gas storage and transportation capacities provides NJRES with a significant amount of arbitrage opportunities that are typically more prevalent during periods of high price volatility.

Predominantly all of NJRES’ purchases and sales of natural gas result in the physical delivery of natural gas. NJRES has elected not to use the normal purchase normal sale scope exception of SFAS 133, Accounting for Derivative Instruments and Hedging Activities, under which related liabilities incurred and assets acquired under these contracts are recorded when title to the underlying commodity passes. Therefore, all NJRES physical commodity contracts are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets with any changes in fair value related to its forward physical sale and purchase contracts recognized as a component of Operating revenues and Gas purchases, respectively, in the Unaudited Condensed Consolidated Statements of Income.

The changes in fair value of NJRES’ financial derivative instruments, which are financial futures, swaps and option contracts, are also recognized in the Unaudited Condensed Consolidated Statements of Income, as a component of Gas purchases.

NJRES’ financial and physical contracts will result, over time, in earning a gross margin on the entire transaction. For financial reporting purposes under GAAP, the change in fair value associated with derivative instruments used to economically hedge these transactions are recorded as a component of Operating revenue and Gas purchases, as appropriate, in the Unaudited Condensed Consolidated Statements of Income during the duration of the financial instrument or commodity contract. These changes in fair value are referred to as unrealized gains and losses. In other instances, certain financial contracts designed to economically fix or hedge the price of natural gas that is purchased and placed into storage, to be sold at a later date, settle and result in realized gains, which are also recorded at the time of settlement as a component of Gas purchases in the Unaudited Condensed Consolidated Statements of Income.

These unrealized gains or losses from the change in fair value of unsettled financial instruments and physical commodity contracts, or realized gains or losses related to financial instruments that economically hedge natural gas inventory that has not been sold as part of a planned transaction, cause large variations in the reported gross margin and earnings of NJRES. NJRES will continue to earn the gross margin established at inception of the transaction over the duration of the forecasted transaction and may be able to capitalize on events in the marketplace that enable it to increase the initial margin; however, gross margin or earnings during periods prior to the delivery of the natural gas will not reflect the underlying economic result.

NJRES expenses its demand charges, which represent the right to use natural gas pipeline and storage capacity assets of a third-party, over the term of the related natural gas pipeline or storage contract. The term of these contracts vary from less than one year to ten years.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Operating Results

NJRES’ unaudited financial results are summarized as follows:

	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands)	2009			2008			2009			2008
Operating revenues	$	283,439		$	801,628		$	1,219,296		$	2,009,751
Gas purchases		313,395			849,616			1,230,061			2,063,564
Gross (Loss)		(29,956	)		(47,988	)		(10,765	)		(53,813	)
Operation and maintenance expense		4,703			6,811			12,931			14,677
Depreciation and amortization		51			50			153			156
Other taxes		323			151			1,248			559
Operating (Loss)		(35,033	)		(55,000	)		(25,097	)		(69,205	)
Other income		172			92			509			244
Interest expense		73			738			244			2,502
Income tax (benefit)		(14,764	)		(22,768	)		(11,004	)		(30,817	)
Net (Loss)	$	(20,170	)	$	(32,878	)	$	(13,828	)	$	(40,646	)

Gross (Loss)

Gross (loss) for the three months ended June 30, 2009, decreased by $18 million, as compared with the same period in the last fiscal year, due primarily to higher realized losses partially offset by lower unrealized losses during the current fiscal period. The combination of these changes in values generated a net unfavorable variance of $(20.7) million in overall values on its financial and physical commodity contracts compared with the same period during fiscal 2008.

NJRES’ results during the quarter ended June 30, 2009, were impacted by the continuing decline in the price of natural gas resulting in realized (losses) associated with natural gas in inventory of $(13.1) million compared to gains of $238 thousand during the same fiscal period in the prior year. The realized (losses) gains pertain to the settlement of certain purchased futures and fixed swap contracts, which economically hedge planned natural gas purchases. The losses incurred during the current fiscal period resulted from a lower settlement price as compared to the original hedge price (or trade price) consistent with a general decline in the market price of natural gas. Conversely, fiscal 2008 was a period of rising commodity prices, therefore NJRES recorded realized gains as a result of settlement prices that were generally higher in comparison to initial trade prices.

As these financial contracts settle, the physical gas is purchased and injected into storage. These physical gas injections and the associated financial hedges are part of the NJRES’ business strategy to subsequently sell the natural gas from storage in the future. The realized amounts are a component of the anticipated financial margin associated with the overall strategy, and as a result of certain accounting requirements, are recognized in current earnings and result in a timing difference until the related gas is sold at which time, NJRES will realize the entire margin on the transaction.

In addition to the realized amounts discussed above, NJRES had unrealized (losses) of $(11.6) million and $(45.6) million during the three months ended June 30, 2009 and 2008, respectively. The unrealized losses relate to certain derivative contracts that have not yet settled. These unrealized amounts represent the change in price of natural gas from the original hedge price as compared to the market price of natural gas at each reporting date, respectively. These unrealized amounts relate to physical and financial contracts that lock in a sale price on the physical gas that will be sold. When NJRES sells the purchased gas, the associated financial hedges will be settled and any previously recognized unrealized amounts related to these transactions will be realized.

Also contributing to the lower margin that resulted from the higher net losses discussed above, was a decrease in storage spreads during the current fiscal period, as described further in the discussion of financial margin in the Non-GAAP measures section.

NJRES had a gross (loss) for the nine months ended June 30, 2009, which decreased by $43 million, as compared with the same period in the last fiscal year, due primarily to an increase of $79.6 million in overall values on its financial and physical commodity contracts, offset by lower margin of $36.6 million primarily related to a decrease in storage spreads and the expiration of a favorable transportation contract as described further in the discussion of financial margin in the Non-GAAP measures section.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

The decline in commodity prices previously discussed also impacted NJRES’ realized and unrealized gains (losses) for the nine months ended June 30, 2009 and 2008. As a result, included in NJRES’ gross (loss) for the nine-month period ended June 30, 2009, were realized (losses) of $(32.9) million compared to gains of $16.9 million during the same period in fiscal 2008. The realized losses recognized during the nine months ended June 30, 2009, relate to a lower market price of natural gas as compared to the original hedged transactions. For the nine months ended June 30, 2008, the inverse was true. In addition, NJRES recognized net unrealized (losses) of $(47.8) million and $(177.1) million during the nine months ended June 30, 2009 and 2008, respectively, due primarily to the change in values related to its short financial derivative contracts and differences in market price movements of the injection hedges relative to the trade price.

Non-GAAP measures

Additionally, management of the Company uses non-GAAP measures, noted as “financial margin” and “net financial earnings”, when evaluating the operating results of NJRES. Since NJRES economically hedges its natural gas purchases and sales with derivative instruments, management uses these measures to compare NJRES’ results against established benchmarks and earnings targets as it eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. Volatility can occur as a result of timing differences surrounding the recognition of certain gains and losses. These timing differences can impact GAAP earnings in two ways:

Unrealized gains and losses on derivatives are recognized in reported earnings in periods prior to physical gas inventory flows; and

Unrealized gains and losses of prior periods are reclassified as realized gains and losses when derivatives are settled in the same period as physical gas inventory movements occur.

Net financial earnings is a measure of the earnings based on eliminating these timing differences, to effectively match the earnings effects of the economic hedges with the physical sale of gas. Consequently, to reconcile from GAAP to both financial margin and net financial earnings, current period unrealized gains and losses on the derivatives are excluded as a reconciling item. Additionally, realized derivative gains and losses are also included in current period net income, however financial margin and net financial earnings include only realized gains and losses related to natural gas sold out of inventory, effectively matching the full earnings effects of the derivatives with realized margins on physical gas flows.

Management views financial margin and net financial earnings as more representative of the overall expected economic result. To the extent that there are unanticipated changes in the markets or to the effectiveness of the economic hedges, NJRES’ non-GAAP results can be different than was originally planned at the beginning of the transaction.

The following table is a computation of financial margin of NJRES:

	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands)	2009			2008			2009		2008
Operating revenues	$	283,439		$	801,628		$	1,219,296	$	2,009,751
Less: Gas purchases		313,395			849,616			1,230,061		2,063,564
Add:
Unrealized loss on derivative instruments		11,612			45,572			47,777		177,071
Effects of economic hedging related to natural gas inventory and certain demand fees		13,057			(238	)		32,854		(16,858	)
Financial (Loss) Margin	$	(5,287	)	$	(2,654	)	$	69,866	$	106,400

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

A reconciliation of Operating loss, the closest GAAP financial measurement, to the Financial margin of NJRES is as follows:

	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands)	2009			2008			2009			2008
Operating (Loss)		(35,033	)		(55,000	)		(25,097	)		(69,205	)
Add:
Operation and maintenance expense		4,703			6,811			12,931			14,677
Depreciation and amortization		51			50			153			156
Other taxes		323			151			1,248			559
Subtotal – Gross (Loss)		(29,956	)		(47,988	)		(10,765	)		(53,813	)
Add:
Unrealized loss on derivative instruments		11,612			45,572			47,777			177,071
Effects of economic hedging related to natural gas inventory and certain demand fees		13,057			(238	)		32,854			(16,858	)
Financial (Loss) Margin	$	(5,287	)	$	(2,654	)	$	69,866		$	106,400

A reconciliation of NJRES Net loss to NJRES Net financial earnings is as follows:

	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands)	2009			2008			2009			2008
Net (Loss)	$	(20,170	)	$	(32,878	)	$	(13,828	)	$	(40,646	)
Add:
Unrealized loss on derivative instruments, net of taxes		7,266			27,833			29,315			108,008
Effects of economic hedging related to natural gas inventory and certain demand fees, net of taxes		8,420			(585	)		20,490			(10,383	)
Net Financial (Losses) Earnings	$	(4,484	)	$	(5,630	)	$	35,977		$	56,979

Financial margin for the three months ended June 30, 2009 and 2008, was $(5.3) million and $(2.7) million, respectively. The decrease of $2.6 million is due primarily to fewer storage arbitrage opportunities, which resulted in lower average price spreads (difference between market sales price and cost) on storage positions for the three-month period ended June 30, 2009, as compared with the same period in the prior fiscal year.

Financial margin for the nine months ended June 30, 2009 and 2008, was $69.9 million and $106.4 million, respectively. The decrease of $36.5 million is due primarily to the expiration of a favorable physical transport capacity contract servicing the Northeast market region that was no longer available for asset optimization in the current fiscal period, along with the transportation portfolio experiencing lower hedged values coupled with higher capacity fees. Transport capacity contracts normally have greater market value during the winter season, when demand levels are usually higher. As a result, the combined operating results of the basis and cash portfolios in the quarter ended June 30, 2009, decreased by $16.8 million, as compared with the same period last fiscal year.

Financial margin from the storage portfolio in the nine months ended June 30, 2009, also decreased by $19.8 million, as compared with the same period in the prior fiscal year, due primarily to lower average spreads on storage positions in the current fiscal period, and less storage capacity, which decreased from 27 Bcf in the prior fiscal period to 26.3 Bcf in the current fiscal period.

Operation and Maintenance Expense (O&M)

Operation and maintenance expense decreased $2.1 million, or 30.9 percent, during the three months ended June 30, 2009, as compared with the same period in the last fiscal year, due primarily to a decrease of $2 million in incentive-based compensation expense during the three months ended June 30, 2009.

O&M expense decreased $1.7 million, or 11.9 percent, during the nine months ended June 30, 2009, as compared with the same period in the last fiscal year, due primarily a decrease of $2.2 million related to incentive compensation as noted above partially offset by a $374,000 increase to legal fees.

Future results are subject to NJRES’ ability to maintain and expand its wholesale marketing activities and are contingent upon many other factors, including an adequate number of appropriate counterparties, volatility in the natural gas market, availability of storage arbitrage opportunities, sufficient liquidity in the energy trading market and continued access to the capital markets.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Retail and Other Operations

The unaudited consolidated financial results of Retail and Other are summarized as follows:

	Three Months Ended June 30,				Nine Months Ended June 30,
(Thousands)	2009		2008		2009			2008
Operating Revenues	$	8,832	$	19,344	$	3,828		$	38,834
Operation and maintenance expense	$	6,431	$	5,892	$	20,293		$	17,030
Equity in earnings, net of tax	$	1,477	$	378	$	2,778		$	1,548
Net Income (Loss)	$	1,881	$	7,802	$	(8,863	)	$	12,479

Operating revenue decreased $10.5 million, or 54.3 percent, and $35 million, or 90.1 percent, respectively for the three months and nine months ended June 30, 2009, to $8.8 million and $3.8 million, respectively as compared with $19.3 million and $38.8 million for the three months and nine months ended June 30, 2008, respectively, due primarily to greater unrealized losses at NJR Energy, which were the result of declining market prices within a portfolio of net long financial derivative positions along with a decrease in installation revenue at NJRHS.

Operation and maintenance expenses for the three months and the nine months ended June 30, 2009, increased $539,000 and $3.3 million, respectively as compared to last fiscal year due primarily to higher labor cost and increased building and utilities expenses and higher health care costs at NJRHS.

Taxes netted in Equity in earnings in the Condensed Consolidated Unaudited Statements of Income from Iroquois were $507,000 and $264,000 for the three months ended June 30, 2009 and 2008, respectively. For the nine months ended June 2009 and 2008, taxes netted in Equity in earnings from Iroquois were $1.4 million and $1 million, respectively. Equity in earnings from Iroquois is driven by the underlying performance of natural gas transportation through its existing pipeline, which is based on FERC regulated tariffs. Similarly, Equity in earnings from Steckman Ridge is driven by storage revenues based on FERC regulated rates. Taxes netted in Equity in earnings from Steckman Ridge were $501,000 for both the three months and nine months ended June 30, 2009.

Net income for the three months and nine months ended June 30, 2009, decreased $5.9 million and $21.3 million, respectively compared with the same periods in the prior fiscal year, due primarily to the decreased operating revenue at NJR Energy and NJRHS and the increased O&M expenses, partially offset by an increase in equity in earnings primarily as a result of the contribution from Steckman Ridge, which became operational during the third quarter of fiscal 2009 and lower income tax expense as a result of the lower Operating income.

NJR Energy has economically hedged a long-term fixed-price contract to sell gas to a counterparty. Unrealized losses or gains at NJR Energy are the result of the change in value associated with financial derivative instruments designed to economically hedge the long-term fixed-price contracts.

The Income statement includes unrealized (gains) losses associated with these derivative instruments of $(484,000) and $(10.9) million for the three months and $17.4 million and $(17.4) million nine months ended June 30, 2009 and 2008, respectively, which are recorded, pre-tax, as a component of Operating revenues.

Additionally, management of the Company uses the non-GAAP measure “net financial earnings”, when viewing the results of NJR Energy to monitor the operational results without the impact of unsettled derivative instruments.

A reconciliation of Net (loss) income to Net financial earnings, a non-GAAP measure, is as follows:

	Three Months Ended June 30,						Nine Months Ended June 30,
(Thousands)	2009			2008			2009			2008
Net income (loss)	$	1,881		$	7,802		$	(8,863	)	$	12,479
Add:
Unrealized (gain) loss on derivative instruments, net of taxes		(285	)		(6,405	)		10,242			(10,226	)
Net financial earnings	$	1,596		$	1,397		$	1,379		$	2,253

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Net financial earnings for the three months ended June 30, 2009, increased $199,000 compared with the same period in the prior fiscal period due primarily to an increase in equity in earnings, which is related to Steckman Ridge, which became operational in April 2009, offset by higher Operations and maintenance expense as discussed above. Net financial earnings decreased $874,000 for the nine months ended June 30, 2009, due primarily to an increase in Operation and maintenance expense, partially offset by an increase in equity in earnings and a decrease in tax expense corresponding to the lower net Operating income.

Liquidity and Capital Resources

NJR’s objective is to maintain a consolidated capital structure that reflects the different characteristics of each business segment and provides adequate financial flexibility for accessing capital markets as required.

NJR’s consolidated capital structure was as follows:

	June 30,			September 30,
	2009			2008
Common stock equity		59	%		51	%
Long-term debt		37			32
Short-term debt		4			17
Total		100	%		100	%

Common stock equity

NJR satisfies its external common equity requirements, if any, through issuances of its common stock, including the proceeds from stock issuances under its Automatic Dividend Reinvestment Plan (DRP) and proceeds from the exercise of options that were granted under the Company’s long-term incentive program. The DRP allows NJR, at its option, to use shares purchased on the open market or newly issued shares. NJR issued approximately 385,000 shares related to the DRP and exercised options during the nine months ended June 30, 2008.

The Company has a share repurchase program that provides for the repurchase of up to 6.8 million shares. As of June 30, 2009, the Company repurchased approximately 5.9 million of those shares and has the ability to repurchase approximately 854,000 additional shares under the approved program.

Debt

NJR and its unregulated subsidiaries rely on cash flows generated from operating activities and utilization of committed credit facilities to provide liquidity to meet working capital and external debt-financing requirements.

As of June 30, 2009, NJR, NJRES and NJNG had committed credit facilities of $605 million with approximately $533 million available under these facilities (see Note 8. Debt).

NJR believes that existing borrowing availability, its current cash balances and its cash flow from operations will be sufficient to satisfy it and its subsidiaries’ working capital, capital expenditure and dividend requirements for the foreseeable future. NJR, NJNG and NJRES currently anticipate that its financing requirements for the next twelve months will be met through the issuance of short-term debt, meter sale lease-backs and proceeds from the Company’s DRP.

NJR

On March 15, 2009, NJR repaid its $25 million, 3.75 percent, Unsecured Senior notes at maturity.

On December 13, 2007, NJR entered into a $325 million, five-year, revolving, unsecured credit facility, which permits the borrowing of revolving loans and swing loans, as well as the issuance of letters of credit. Swing loans are loans made available on a same-day basis for an aggregate principal amount of up to $50 million and repayable in full within a maximum of seven days of borrowing. It also permits an increase to the facility, from time to time, with the existing or new lenders, in a minimum of $5 million increments up to a maximum $100 million at the lending banks discretion. Borrowings under the new facility are conditional upon compliance with a maximum leverage ratio, as defined in the new credit facility, of not more than 0.65 to 1.00 at any time. NJR used the initial borrowings under the new credit facility to refinance its prior credit facility. In addition, certain of NJR’s non-regulated subsidiaries have guaranteed to the lenders all of NJR’s obligations under the new credit facility. Depending on borrowing levels and credit ratings, NJR’s interest rate can either be, at its discretion, the London inter-bank offered rate (“LIBOR”) or the Federal Funds Open Rate plus an applicable spread and facility fee.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

As of June 30, 2009, NJR has a $23 million letter of credit outstanding on behalf of NJRES, which is used for margin requirements for natural gas transactions and will expire on December 31, 2009.

NJR also has a $675,000 letter of credit outstanding on behalf of CR&R, which will expire on December 3, 2009. The letter of credit is in place to support development activities.

NJR uses its short term borrowings primarily to finance its share repurchases, to satisfy NJRES’ short term liquidity needs and to finance, on an initial basis, unregulated investments. NJRES’ use of high-injection, high-withdrawal storage facilities and anticipated pipeline park-and-loan arrangements, combined with related economic hedging activities in the volatile wholesale natural gas market, create significant short-term cash requirements.

NJNG

NJNG satisfies its debt needs by issuing short- and long-term debt based upon its own financial profile. The seasonal nature of NJNG’s operations creates large short-term cash requirements, primarily to finance natural gas purchases and customer accounts receivable. NJNG obtains working capital for these requirements, and for the temporary financing of construction and MGP remediation expenditures and energy tax payments, through the issuance of commercial paper and short-term bank loans.

On November 1, 2008, upon maturity, NJNG redeemed its $30 million, 6.27 percent, Series X First Mortgage bonds.

To support the issuance of commercial paper, NJNG has a $250 million committed credit facility with several banks, with a 5-year term, expiring in December 2009. NJNG currently plans to renew or replace this facility prior to or upon its expiration. NJNG had no borrowings supported by the credit facility as of June 30, 2009. In addition, borrowings under NJNG’s credit facility are conditioned upon compliance with a maximum leverage ratio, as defined in the credit facility, of not more than 0.65 to 1.00 at any time and a minimum interest coverage ratio, as defined in the credit facility, of less than 2.50 to 1.00.

Neither NJNG nor its assets are obligated or pledged to support the NJR or NJRES facilities.

NJRES

NJRES has a 3-year, $30 million committed credit facility with a multinational financial institution. Borrowings under this facility are guaranteed by NJR. There were no borrowings under this facility as of June 30, 2009.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Contractual Obligations

The following table is a summary of NJR, NJNG and NJRES contractual cash obligations and financial commitments and their applicable payment due dates as of June 30, 2009:

(Thousands)	Total		Up to 1 Year		2-3 Years		4-5 Years		After 5 Years
Long-term debt (1)	$	523,075	$	17,086	$	51,766	$	90,707	$	363,516
Capital lease obligations (1)		86,616		9,748		22,093		15,709		39,066
Operating leases (1)		10,985		3,047		4,100		2,439		1,399
Short-term debt		48,600		48,600		—		—		—
New Jersey Clean Energy Program (1)		39,960		10,805		23,293		5,862		—
Construction obligations		2,019		2,019		—		—		—
Remediation expenditures (2)		120,230		11,051		31,349		8,300		69,530
Natural gas supply purchase obligations–NJNG		42,094		35,570		6,524		—		—
Demand fee commitments–NJNG		723,020		94,953		192,849		165,146		270,072
Natural gas supply purchase obligations–NJRES		715,891		411,402		262,485		42,004		—
Demand fee commitments–NJRES		205,857		82,303		65,663		30,438		27,453
Total contractual cash obligations	$	2,518,347	$	726,584	$	660,122	$	360,605	$	771,036

(1)

These obligations include an interest component, as defined under the related governing agreements or in accordance with the applicable tax statute.

(2)

Expenditures are estimated

(3)

As of June 30, 2009, we had a liability for unrecognized tax benefits of $6.5 million. We cannot make a reasonable estimate of the period of cash settlement for the liability for unrecognized tax benefits. See Note 13 to the consolidated financial statements, Income Taxes, for a further discussion on our income tax positions.

For fiscal 2009, the Company has no minimum pension funding requirements, however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in demographic factors. On June 12, 2009, NJR made a discretionary contribution of $1 million to the Pension plan. It is anticipated that the annual funding level to the OPEB plans will range from $1.2 million to $1.4 million over the next five years. Additional contributions may be made based on market conditions and various assumptions.

As of June 30, 2009, there were NJR guarantees covering approximately $356 million of natural gas purchases and demand fee commitments of NJRES and NJNG, included in natural gas supply purchase obligations above, not yet reflected in Accounts payable on the Unaudited Condensed Consolidated Balance Sheet.

The Company is obligated to fund up to $132.5 million associated with the construction and development of Steckman Ridge. Currently, NJR anticipates that Steckman Ridge could seek non-recourse project financing for a portion of the facility once construction activities are completed, therefore potentially reducing the aggregate recourse amount funded by NJR. There can be no assurances that Steckman Ridge will eventually secure such non-recourse project financing.

Total capital expenditures for fiscal 2009 are estimated at $87.1 million, including an estimate of $6 million related to the AIP construction costs.

Off-Balance-Sheet Arrangements

The Company does not have any off-balance-sheet financing arrangements.

Cash Flow

Operating Activities

As presented in the Unaudited Condensed Consolidated Statements of Cash Flows, cash flow from operating activities totaled $350.7 million for the nine months ended June 30, 2009, compared with cash flow from operations of $144.3 million for the same period in fiscal 2008. NJR employs the indirect method when preparing its Unaudited Condensed Consolidated Statement of Cash Flows. Net income is adjusted for any non-cash items, such as accruals and certain amortization amounts that impact earnings during the period. In addition, operating cash flows are primarily affected by variations in working capital and the related changes in the beginning and period end balances, which can be impacted by the following:

seasonality of NJR’s business;

fluctuations in wholesale natural gas prices;

timing of storage injections and withdrawals;

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

management of the deferral and recovery of gas costs;

changes in contractual assets utilized to optimize margins related to natural gas transactions; and

timing of the collections of receivables and payments of current liabilities.

A summary of the primary factors that contributed to the increase in operating cash flows during the nine months ended June 30, 2009, as compared with the prior fiscal period is as follows:

lower costs associated with natural gas inventory at NJRES due primarily to the decline in commodity prices during fiscal 2009 compared to rising prices during fiscal 2008. As a general indicator, NYMEX prices declined approximately 58 percent during fiscal 2009 compared with an increase of approximately 119 percent during the prior fiscal period;

a reduction in receivable balances at NJRES stemming from a 55 percent decrease in average sales price in fiscal 2009 compared with an increase in receivable balances during the nine months ended June 30, 2008, which resulted from a 25 percent increase in volumes coupled with a 113 percent increase in average sales prices;

an increase in NJNG’s gas costs recovered during fiscal 2009 as a result of gas costs falling below the commodity component of NJNG’s BGSS rate billed to its customers compared with the nine months ended June 30, 2008. The amount of gas costs overrecovered was moderated by a BGSS refund of $30 million issued to NJNG’s customers during fiscal 2008 and temporary rate credits of $45 million during fiscal 2009;

reduced margin requirements at NJRES during the current fiscal year compared with higher deposits during the same period in fiscal 2008 as a result of the adverse impact of rising NYMEX prices to NJRES’ short futures positions.

These increases in operating cash flows were offset by a decrease in NJRES payable balances primarily related to a decrease in the cost of purchases during the current fiscal period.

NJNG’s MGP expenditures are currently expected to total $11.1 million in fiscal 2009 (see Note 14. Commitments and Contingent Liabilities).

Investing Activities

Cash flow used in investing activities totaled $92.7 million for the nine months ended June 30, 2009, compared with $74.7 million in the same period in fiscal 2008. The increase in cash used was due primarily to an increase in the cash invested in Steckman Ridge and higher NJNG utility plant expenditures offset by the drawdown from the restricted cash construction fund.

On June 5, 2008, the Federal Energy Regulatory Commission (FERC) issued Steckman Ridge a certificate of public convenience and necessity authorizing the ownership, construction and operation of its natural gas storage facility and associated facilities. On April 1, 2009, Steckman Ridge received authorization to place certain injection related facilities into commercial operation. Customers have begun to inject natural gas inventory in preparation for the initial withdrawal season. Construction will continue through the summer of 2009 as more facilities are made ready to support the initial winter season. As of June 30, 2009, NJR has invested $120 million in Steckman Ridge. This amount excludes capitalized interest and other direct costs. Total project costs related to the development of the storage facility are currently estimated at approximately $265 million, of which NJR is obligated to fund 50 percent or approximately $132.5 million. NJR anticipates that Steckman Ridge could seek non-recourse financing upon full completion of the construction and development of its facilities, thereby potentially reducing the final expected recourse obligation of NJR. There can be no assurances that such non-recourse project financing will be secured or available for Steckman Ridge.

Retail and Other capital expenditures each year have been made primarily in connection with investments made to preserve the value of real estate holdings. At June 30, 2009, CR&R owned 83 acres of undeveloped land and a 56,400-square-foot building on 5 acres of land.

NJRES does not currently anticipate any significant capital expenditures in fiscal 2009.

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New Jersey Resources Corporation

Part I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued)

Financing Activities

Cash flow used in financing activities totaled $223.6 million for the nine months ended June 30, 2009, compared with $48.8 million for the same period in the prior fiscal year. During the current fiscal period, NJNG repaid its $30 million, 6.27 percent, Series X Mortgage bonds and NJR repaid its $25 million, 3.75 percent, unsecured senior notes. In addition, the Company was able to reduce its short-term borrowings as a result of its improved cash from operations.

NJNG provides funding for certain of its infrastructure projects through tax exempt, variable-rate debt, which has been issued to back six series of auction rate securities (ARS) through the Economic Development Authority of New Jersey (EDA), and are based on the borrowing costs of the ARS. During periods of reduced liquidity for ARS, NJNG’s rate on its variable rate debt could default to a maximum rate of the lesser of (i) 175 percent of the 30-day LIBOR or (ii) 10 to 12 percent, as applicable to a particular series of ARS. Although its average weighted interest rate has decreased to a rate of 0.6 percent as of June 30, 2009, NJNG continues to review alternatives that would eliminate or mitigate the inherent interest rate risk associated with its variable rate debt.

Credit Ratings

The table below summarizes NJNG’s current credit ratings issued by two rating entities, Standard and Poor’s (S&P) and Moody’s Investors Service, Inc. (Moody’s):

	Standard and Poor’s	Moody’s
Corporate Rating	A	N/A
Commercial Paper	A-1	P-1
Senior Secured	A+	Aa3
Ratings Outlook	Stable	Negative

NJNG’s S&P and Moody’s ratings are investment-grade ratings. S&P and Moody’s give NJNG’s commercial paper the highest rating within the Commercial Paper investment-grade category. NJR is not a rated entity. On April 30, 2009, S&P affirmed its ratings and changed its outlook from negative to stable.

NJNG is not party to any lending agreements that would accelerate the maturity date of any obligation caused by a failure to maintain any specific credit rating. If such ratings are downgraded below investment grade, borrowing costs could increase, as will the costs of maintaining certain contractual relationships and for future financing. Even if ratings are downgraded without falling below investment grade, NJR and NJNG may still face increased borrowing costs under their respective credit facilities. A rating set forth above is not a recommendation to buy, sell or hold the Company’s or NJNG’s securities and may be subject to revision or withdrawal at any time. Each rating set forth above should be evaluated independently of any other rating.

The timing and mix of any external financings will target a common equity ratio that is consistent with maintaining the Company’s current short- and long-term credit ratings.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Financial Risk Management

Commodity Market Risks

Natural gas is a nationally traded commodity, and its prices are determined effectively by the New York Mercantile Exchange (NYMEX) and over-the-counter markets. The prices on the NYMEX and over-the-counter markets generally reflect the notional balance of natural gas supply and demand, but are also influenced significantly from time to time by other events.

The regulated and unregulated natural gas businesses of the Company and its subsidiaries are subject to market risk due to fluctuations, in the price of natural gas. To economically hedge against such fluctuations, the Company and its subsidiaries have entered into futures contracts, options agreements and swap agreements. To manage these derivative instruments, the Company has well-defined risk management policies and procedures that include daily monitoring of volumetric limits and monetary

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New Jersey Resources Corporation

Part I

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)

guidelines. The Company’s natural gas businesses are conducted through three of its operating subsidiaries. First, NJNG is a regulated utility that uses futures, options and swaps to economically hedge against price fluctuations and its recovery of natural gas costs is regulated by the BPU. Second, NJRES uses futures, options and swaps to economically hedge purchases and sales of natural gas. Finally, NJR Energy has entered into two swap transactions related to an 18-year fixed-price contract, expiring in October 2010 to sell remaining volumes of approximately 3.2 Bcf of natural gas (Gas Sales Contract) to an energy marketing company.

The following table reflects the changes in the fair market value of financial derivatives related to natural gas purchases and sales from September 30, 2008 to June 30, 2009:

(Thousands)	Balance September 30, 2008			Increase (Decrease) in Fair Market Value			Less Amounts Settled			Balance June 30, 2009
NJNG	$	(49,610	)	$	(72,061	)	$	(74,375	)	$	(47,296	)
NJRES		89,571			100,251			140,286			49,536
NJR Energy		20,190			(21,034	)		(3,651	)		2,807
Total	$	60,151		$	7,156		$	62,260		$	5,047

There were no changes in methods of valuations during the quarter ended June 30, 2009.

The following is a summary of fair market value of financial derivatives related to natural gas purchases and sales at June 30, 2009, by method of valuation and by maturity for each fiscal year period:

(Thousands)	2009			2010			2011-2013		After 2013		Total Fair Value
Price based on NYMEX	$	(19,018	)	$	13,664	$	(2,731	)		—	$	(8,085	)
Price based on other external data		6,319			6,325		488			—		13,132
Total	$	(12,699	)	$	19,989	$	(2,243	)		—	$	5,047

The following is a summary of financial derivatives by type as of June 30, 2009:

		Volume (Bcf)			Price per Mmbtu		Amounts included in Derivatives (Thousands)
NJNG	Futures		8.4		$	3.65 - $9.19	$	(46,913	)
	Swaps		(0.3	)	$	3.69 - $6.19		(4,375	)
	Options		11.5		$	3.65 - $9.50		3,992
NJRES	Futures		(16.3	)	$	3.51 - $10.89		23,837
	Swaps		(18.0	)	$	2.88 - $12.42		25,699
	Options		2.5		$	3.30 - $3.65		—
NJR Energy	Swaps		3.2		$	3.38 - $ 4.47		2,807
Total							$	5,047

The following table reflects the changes in the fair market value of physical commodity contracts from September 30, 2008 to June 30, 2009:

(Thousands)		Balance September 30, 2008				Increase (Decrease) in Fair Market Value				Less Amounts Settled				Balance June 30, 2009
NJRES		$	1,714			$	22,883			$	12,102			$	12,495

The Company uses a value-at-risk (VaR) model to assess the market risk of its net futures, options and swap positions. VaR represents the potential loss in value of NJRES’ trading portfolio due to adverse market movements over a defined time horizon (NJRES utilizes holding periods of 1 day and 10 days) with a specified confidence level (NJRES utilizes either a 95 percent or 99 percent confidence level). As an example, utilizing a 1 day holding period with a 95 percent confidence level would indicate that there is a 5 percent chance that the liquidation value of the NJRES portfolio would fall below the expected trading value by an amount at least as large as the calculated VaR.

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New Jersey Resources Corporation

Part I

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)

The VaR at June 30, 2009, using the variance-covariance method with a 95 percent confidence level and a 1-day holding period, was $622,000. The VaR with a 99 percent confidence level and a 10-day holding period was $2.8 million. The calculated VaR represents an estimate of the potential change in the value of the net positions. These estimates may not be indicative of actual results because actual market fluctuations may differ from forecasted fluctuations.

Wholesale Credit Risk

NJNG, NJRES and NJR Energy engage in wholesale marketing activities. NJR monitors and manages the credit risk of its wholesale marketing operations through credit policies and procedures that management believes reduce overall credit risk. These policies include a review and evaluation of prospective counterparties’ financial statements and/or credit ratings, daily monitoring of counterparties’ credit limits, daily communication with traders regarding credit status and the use of credit mitigation measures, such as minimum margin requirements, collateral requirements and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin deposit.

The Company’s Risk Management Committee (RMC) continuously monitors NJR’s credit risk management policies and procedures. The RMC is comprised of individuals from NJR-affiliated companies that meet twice a month and, among other things, evaluates the effectiveness of existing credit policies and procedures, reviews material transactions and discusses emerging issues.

The following is a summary of gross and net credit exposures, grouped by investment and noninvestment grade counterparties, as of June 30, 2009. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts plus any outstanding receivable for the value of natural gas delivered for which payment has not yet been received. Net credit exposure is defined as gross credit exposure reduced by collateral received from counterparties and/or payables, where netting agreements exist. The amounts presented below exclude accounts receivable for retail natural gas sales and services.

Unregulated counterparty credit exposure as of June 30, 2009, is as follows:

(Thousands)	Gross Credit Exposure		Net Credit Exposure
Investment grade	$	104,582	$	64,424
Noninvestment grade		13,159		5,525
Internally rated investment grade		19,585		10,903
Internally rated noninvestment grade		3,975		1,021
Total	$	141,301	$	81,873

NJNG’s counterparty credit exposure as of June 30, 2009, is as follows:

(Thousands)	Gross Credit Exposure		Net Credit Exposure
Investment grade	$	15,347	$	12,332
Noninvestment grade		634		—
Internally rated investment grade		269		35
Internally rated noninvestment grade		143		—
Total	$	16,393	$	12,367

Due to the inherent volatility in the prices of natural gas commodities and derivatives, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty failed to perform the obligations under its contract (for example, failed to deliver or pay for natural gas), then the Company could sustain a loss. This loss would comprise the loss on natural gas delivered but not paid for and/or the cost of replacing natural gas not delivered at a price higher than the price in the original contract. Any such loss could have a material impact on the Company’s financial condition, results of operations or cash flows.

Interest Rate Risk–Long-Term Debt

As of June 30, 2009, the Company (excluding NJNG) had no variable-rate long-term debt.

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Part I

ITEM 4. CONTROLS AND PROCEDURES

As of June 30, 2009, NJNG is obligated with respect to loan agreements securing six series of auction rate bonds totaling approximately $97 million of variable-rate debt backed by securities issued by the EDA. The EDA bonds are ARS and have an interest rate reset every 7 or 35 days, depending upon the applicable series, when an auction is held for the purposes of determining the interest rate pricing of the securities. The interest rate associated with the NJNG variable-rate debt is based on the rates the EDA receives from its ARS. As of June 30, 2009, all of the auctions surrounding the EDA ARS have failed, resulting in the securities bearing interest at their maximum rates, as defined as the lesser of (i) 175 percent of 30-day LIBOR or (ii) 10 to 12 percent per annum, as applicable to such series of ARS. While the failure of the ARS auctions has no default impact on NJNG’s variable-rate debt, it does impact its borrowing costs of the variable-rate debt. As such, NJNG currently has a weighted average interest rate of 0.6 percent as of June 30, 2009. There can be no assurance that the ARS securities of the EDA will have enough market liquidity to avoid failed auctions in the future.

Effects of Inflation

Although inflation rates have been relatively low to moderate in recent years, any change in price levels has an effect on operating results due to the capital-intensive and regulated nature of the Company’s utility subsidiary. The Company attempts to minimize the effects of inflation through cost control, productivity improvements and regulatory actions where appropriate.

Disclosure Controls and Procedures

As discussed in "Part II. Item 9A. Controls and Procedures" in our Form 10-K for the fiscal year ended September 30, 2008, in connection with the Company’s preparation of its consolidated financial statements for the fiscal year ended September 30, 2008, the Company identified an immaterial error in the recording of certain physical natural gas transactions, which were not recorded at the appropriate fair value during the interim quarters ended March 31, 2008 and June 30, 2008, as they were valued at an incorrect price. Controls were not designed properly or operating effectively to prevent or detect these pricing errors. Natural gas prices are volatile and it is reasonably possible that the volume of these transactions could have been larger during any interim period or for the fiscal year ended September 30, 2008. The Company concluded that it was reasonably possible that this control weakness could have resulted in a material error in its Consolidated Financial Statements had the volume of these transactions been larger.

As of June 30, 2009, under the supervision and with the participation of the Company’s management, including the principal executive officer and principal financial officer, the Company conducted an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)) under the Exchange Act, as of the end of the period covered by this report. Based on this evaluation, since the material weakness discussed above is not completely remediated, the Company’s principal executive officer and principal financial officer concluded that, as of end of the period covered by this report, the Company’s disclosure controls and procedures were not effective to ensure that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act, is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to the Company’s management, including its principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

In addition, in conjunction with the filing of this amended Form 10-Q/A, as a result of the restatement described in Note 2 to the Unaudited Condensed Consolidated Financial Statements, under the supervision and with the participation of the Company’s management, including the principal executive officer and principal financial officer, the Company conducted a re-evaluation of the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)) under the Exchange Act, as of the end of the period covered by this report. Management, in consultation with the Audit Committee, has concluded that the restatement errors set forth herein constituted a material weakness in the Company’s internal controls over financial reporting as of the date of the original filing, which has since been remediated.

The financial statements for the period covered by this report were prepared with particular attention to the material weakness. Accordingly, management believes that the condensed consolidated financial statements included in this Quarterly Report fairly present, in all material respects, our financial condition, results of operations and cash flows as of and for the periods presented.

The Company continually reviews its disclosure controls and procedures and makes changes, as necessary, to ensure the quality of its financial reporting. As detailed below, the Company has implemented certain additional controls that it believes will significantly reduce the potential for similar issues to arise in the future.

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New Jersey Resources Corporation

Part I

ITEM 4. CONTROLS AND PROCEDURES (Continued)

Changes in Internal Control over Financial Reporting

Management and the Board of Directors are committed to the remediation of the material weaknesses set forth above as well as the continued improvement of the Company’s overall system of internal control over financial reporting. Management is in the process of actively addressing and remediating the material weaknesses in internal control over financial reporting described above. Subsequent to the quarter and fiscal year ended September 30, 2008, in connection with the material weaknesses in internal control over financial reporting detailed above, the Company has implemented or will implement the following controls designed to substantially reduce the risk of a similar material weaknesses occurring in the future:

expand training, education and accounting reviews for all relevant personnel involved in the accounting treatment and disclosures for the Company’s commodity transacting;

invest in additional resources with appropriate accounting technical expertise, including the hiring of a Controller-Unregulated Operations in April 2009;

expand the review of the design of the internal control over financial reporting related to the accounting of commodity transacting, which will incorporate an analysis of the current staffing levels, job assignments and the design of all internal control processes for the accounting for commodity transacting and implement new and improved processes and controls, if warranted; and

increase the level of review and discussion of significant accounting matters and supporting documentation with senior finance management.

As part of the Company’s fiscal 2009 assessment of internal control over financial reporting, management will conduct sufficient testing and evaluation of the controls to be implemented as part of this remediation plan to ascertain that they are designed and are operating effectively. The effectiveness of remediation efforts will not be known until the Company can test those controls in connection with the management tests of internal control over financial reporting that the Company will perform during fiscal 2009. Management believes, however, these measures will remediate the above identified material weakness in internal control over financial reporting.

These were the only changes in the Company’s internal control over financial reporting (as such term is defined in Exchange Act Rule 13a-15(f)) that occurred during the quarter ended June 30, 2009, that have materially affected, or are reasonably likely to materially affect, internal control over financial reporting. Subsequent to the end of the third fiscal quarter, the Company upgraded its JD Edwards Oracle Enterprise Resource Planning (“ERP”) software system to improve functionality associated with the system’s finance, human resources, supply chain and work management modules. For the quarter ended June 30, 2009, all of the related processes were completed prior to the upgrade. Management concluded that it did not need to make any changes to its internal control over financial reporting as a result of this upgrade.

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ITEM 1. LEGAL PROCEEDINGS

Information regarding reportable legal proceedings is contained in Part I, "Item 3. Legal Proceedings" in NJR’s Annual Report on Form 10-K for the year ended September 30, 2008, and is set forth in Part I, Item 1, Note 14, Commitment and Contingent Liabilities—Legal Proceedings in the Unaudited Condensed Consolidated Financial Statements. No legal proceedings became reportable during the quarter June 30, 2009, and there have been no material developments during such quarter regarding any previously reported legal proceedings, which have not been previously disclosed.

ITEM 1A. RISK FACTORS

While NJR attempts to identify, manage and mitigate risks and uncertainties associated with its business to the extent practical, under the circumstances, some level of risk and uncertainty will always be present. Part I, Item 1A, "Risk Factors," of NJR’s 2008 Annual Report on Form 10-K includes a detailed discussion of NJR’s risk factors. These risks and uncertainties have the potential to materially affect NJR’s financial condition and results of operations. There have not been any material changes from the risk factors as previously disclosed by NJR in the 2008 Annual Report on Form 10-K.

ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS

In 1996, the NJR Board of Directors (“Board”) authorized the Company to implement a share repurchase program, which has been expanded several times since the inception of the program. On November 14, 2007, the Board authorized an increase to the plan to permit the repurchase, in the open market or in privately negotiated transactions, of 1.5 million shares, bringing the total permitted repurchases to 6.8 million shares as of that date. As of June 30, 2009, the Company has 854,000 shares of its common stock still available for repurchase.

The following table sets forth NJR’s repurchase activity for the quarter ended June 30, 2009:

Period	Total Number of Shares (or Units) Purchased		Average Price Paid per Share (or Unit)		Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares (or Units) That May Yet be Purchased Under the Plans or Programs
04/01/09 – 04/30/09		246,700		32.65		246,700		1,056,271
05/01/09 – 05/31/09		202,100		31.70		202,100		854,171
06/01/09 – 06/30/09		—		—		—		854,171
Total		448,800		—		448,800		854,171

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ITEM 6. EXHIBITS

31.1		Certification of the Chief Executive Officer pursuant to section 302 of the Sarbanes-Oxley Act

31.2		Certification of the Chief Financial Officer pursuant to section 302 of the Sarbanes-Oxley Act

32.1		Certification of the Chief Executive Officer pursuant to section 906 of the Sarbanes-Oxley Act*

32.2		Certification of the Chief Financial Officer pursuant to section 906 of the Sarbanes-Oxley Act*

*This certificate accompanies this report pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and shall not be deemed filed by NJR for purposes of Section 18 or any other provision of the Securities Exchange Act of 1934, as amended.

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SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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.

	NEW JERSEY RESOURCES CORPORATION
	(Registrant)

Date: November 24, 2009
	By:/s/ Glenn C. Lockwood
	Glenn C. Lockwood
	Senior Vice President and
	Chief Financial Officer