Hess - 10-Q quarterly report FY

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q


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

For the quarter ended September 30, 2002


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

For the transition period from _____ to _____.

Commission File Number 1-1204

AMERADA HESS CORPORATION

(Exact name of registrant as specified in its charter)

DELAWARE
(State or other jurisdiction of incorporation or organization)

13-4921002
(I.R.S. employer identification number)

1185 AVENUE OF THE AMERICAS, NEW YORK, N.Y.
(Address of principal executive offices)
10036
Zip Code

(Registrant’s telephone number, including area code is (212) 997-8500)

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

At September 30, 2002, 89,200,930 shares of Common Stock were outstanding.

TABLE OF CONTENTS


PART I — FINANCIAL INFORMATION
	Item 1. Financial Statements
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
	Item 2. Management’s Discussion and Analysis of Results of Operations and Financial Condition
	Item 3. Quantitative and Qualitative Disclosures About Market Risk
	Item 4. Controls and Procedures
PART II - OTHER INFORMATION
	Item 1. Legal Proceedings
	Item 6. Exhibits and Reports on Form 8-K
SIGNATURES
CERTIFICATIONS
CERTIFICATION OF CHAIRMAN OF THE BOARD AND CEO
CERTIFICATION OF EXECUTIVE VICE PRESIDENT AND CFO

PART I — FINANCIAL INFORMATION

Item 1. Financial Statements

AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED INCOME

(in millions, except per share data)


				Three Months					Nine months
				ended September 30					ended September 30

				2002			2001		2002			2001

REVENUES




	Sales (excluding excise taxes) and other operating revenues			$	2,818		$	2,888	$	8,635		$	10,531




	Non-operating income




		Equity in income (loss) of HOVENSA L.L.C.			(6	)		11		(50	)		77




		Other			83			35		162			120

			Total revenues		2,895			2,934		8,747			10,728

COSTS AND EXPENSES




	Cost of products sold				1,629			1,848		5,118			7,016




	Production expenses				222			196		589			522




	Marketing expenses				144			161		500			466




	Exploration expenses, including dry holes and lease impairment				105			75		209			232




	Other operating expenses				49			54		145			163




	General and administrative expenses				72			71		195			195




	Interest expense				64			51		204			132




	Depreciation, depletion and amortization				342			254		1,012			664




	Asset impairment				394			- -		394			- -

			Total costs and expenses		3,021			2,710		8,366			9,390

	Income (loss) before income taxes				(126	)		224		381			1,338




	Provision for income taxes				10			57		228			478

NET INCOME (LOSS)				$	(136	)	$	167	$	153		$	860

NET INCOME (LOSS) PER SHARE




		BASIC		$	(1.54	)	$	1.90	$	1.74		$	9.76

		DILUTED		$	(1.54	)	$	1.86	$	1.72		$	9.63

WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING					88.3			89.4		89.3			89.3




COMMON STOCK DIVIDENDS PER SHARE				$	.30		$	.30	$	.90		$	.90

See accompanying notes to consolidated financial statements.

PART I — FINANCIAL INFORMATION (CONT’D.)

AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(in millions of dollars, thousands of shares)

ASSETS


			September 30,			December 31,
			2002			2001

CURRENT ASSETS




	Cash and cash equivalents		$	48		$	37




	Accounts receivable			1,773			2,962




	Inventories			522			550




	Other current assets			131			397

		Total current assets		2,474			3,946

INVESTMENTS AND ADVANCES




	HOVENSA L.L.C.			839			889




	Other			769			747

		Total investments and advances		1,608			1,636

PROPERTY, PLANT AND EQUIPMENT




	Total — at cost			16,593			16,627




	Less reserves for depreciation, depletion, amortization and lease impairment			8,852			8,462

		Property, plant and equipment — net		7,741			8,165

NOTES RECEIVABLE				376			395

GOODWILL				977			982

DEFERRED INCOME TAXES AND OTHER ASSETS				451			245

TOTAL ASSETS			$	13,627		$	15,369

LIABILITIES AND STOCKHOLDERS’ EQUITY




CURRENT LIABILITIES




	Accounts payable — trade		$	1,267		$	1,807




	Accrued liabilities			791			1,115




	Taxes payable			304			414




	Notes payable			3			106




	Current maturities of long-term debt			15			276

		Total current liabilities		2,380			3,718

LONG-TERM DEBT				5,065			5,283

DEFERRED LIABILITIES AND CREDITS




	Deferred income taxes			1,196			1,111




	Other			303			350

		Total deferred liabilities and credits		1,499			1,461

STOCKHOLDERS’ EQUITY




	Preferred stock, par value $1.00, 20,000 shares authorized 3% cumulative convertible series Authorized - 330 shares Issued - 327 shares ($16 million liquidation preference)			- -			- -




	Common stock, par value $1.00 Authorized - 200,000 shares Issued - 89,201 shares at September 30, 2002; 88,757 shares at December 31, 2001			89			89




	Capital in excess of par value			932			903




	Retained earnings			3,880			3,807




	Accumulated other comprehensive income (loss)			(218	)		108

		Total stockholders’ equity		4,683			4,907

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY			$	13,627		$	15,369

See accompanying notes to consolidated financial statements.

PART I — FINANCIAL INFORMATION (CONT’D.)

AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES

STATEMENT OF CONSOLIDATED CASH FLOWS

Nine months ended September 30

(in millions)


				2002			2001

CASH FLOWS FROM OPERATING ACTIVITIES




	Net income			$	153		$	860




	Adjustments to reconcile net income to net cash provided by operating activities




		Depreciation, depletion and amortization			1,012			664




		Asset impairment			394			- -




		Exploratory dry hole costs			99			122




		Lease impairment			33			24




		Gain on asset sales			(103	)		- -




		Provision (benefit) for deferred income taxes			(70	)		99




		Undistributed earnings of affiliates			52			(68	)

					1,570			1,701




		Changes in operating assets and liabilities			(143	)		(67	)

			Net cash provided by operating activities		1,427			1,634

CASH FLOWS FROM INVESTING ACTIVITIES




	Capital expenditures				(1,207	)		(1,981	)




	Acquisition of Triton Energy Limited, net of cash				- -			(2,720	)




	Payment received on note				48			48




	Proceeds from asset sales and other				363			(31	)

			Net cash used in investing activities		(796	)		(4,684	)

CASH FLOWS FROM FINANCING ACTIVITIES




	Increase (decrease) in notes payable				(103	)		52




	Long-term borrowings				597			2,891




	Repayment of long-term debt				(1,035	)		(5	)




	Cash dividends paid				(107	)		(94	)




	Common stock acquired				- -			(100	)




	Stock options exercised				28			59

			Net cash provided by (used in) financing activities		(620	)		2,803

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS					11			(247	)




CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR					37			312

CASH AND CASH EQUIVALENTS AT END OF PERIOD				$	48		$	65

See accompanying notes to consolidated financial statements.

PART I — FINANCIAL INFORMATION (CONT’D.)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS


Note 1 -		The financial statements included in this report reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of the Corporation’s consolidated financial position at September 30, 2002 and December 31, 2001, and the consolidated results of operations for the three- and nine-month periods ended September 30, 2002 and 2001 and the consolidated cash flows for the nine-month periods ended September 30, 2002 and 2001. The unaudited results of operations for the interim periods reported are not necessarily indicative of results to be expected for the full year.




		Certain notes and other information have been condensed or omitted from these interim financial statements. These statements, therefore, should be read in conjunction with the consolidated financial statements and related notes included in the 2001 Annual Report to Stockholders, which have been incorporated by reference in the Corporation’s Form 10-K for the year ended December 31, 2001.




Note 2 -		In the third quarter of 2002, the Corporation recorded an impairment of $394 million ($256 million after income taxes) to reduce the carrying value of certain producing oil and gas fields and exploration acreage in the Gulf of Mexico to their estimated fair values. The impairment principally reflects reduced reserve estimates on these fields. Estimated fair values were determined by discounting anticipated future net cash flows.




Note 3 -		In September 2002, the Corporation recorded a gain of $103 million ($67 million after income taxes) from the sale of six United States flag tankers and ancillary assets. In connection with this sale, the Corporation has agreed to support the buyer’s charter hire rates for these vessels for up to five years. Consequently, the Corporation has deferred a pre-tax gain of $50 million as part of the sale transaction to reflect potential obligations under the support agreement.




Note 4 -		Inventories consist of the following (in millions):


		September 30,			December 31,
		2002			2001

Crude oil and other charge stocks		$	94		$	108




Refined and other finished products			477			440




Less: LIFO adjustment			(222	)		(111	)

			349			437




Materials and supplies			173			113

	Total inventories	$	522		$	550

PART I — FINANCIAL INFORMATION (CONT’D.)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS


Note 5 -		The Corporation accounts for its investment in HOVENSA L.L.C. using the equity method. Summarized financial information for HOVENSA follows (in millions):


				At		At
				September 30,		December 31,
				2002		2001

Balance sheet




Assets




	Current assets			$	474	$	491




	Net fixed assets				1,908		1,846




	Other assets				31		35

		Total assets		$	2,413	$	2,372

Liabilities and partners’ equity




	Current liabilities			$	383	$	294




	Long-term debt				397		365




	Deferred liabilities and credits				34		23




	Partners’ equity				1,599		1,690

			Total liabilities and partners’ equity	$	2,413	$	2,372


		Three months					Nine months
		ended September 30					ended September 30

		2002			2001		2002			2001

Income statement




Total revenues		$	1,054		$	1,058	$	2,622		$	3,403




Costs and expenses			1,065			1,035		2,720			3,246

	Net income (loss)	$	(11	)	$	23	$	(98	)	$	157

Amerada Hess Corporation’s share		$	(6	)	$	11	$	(50	)	$	77


		In connection with the startup of the new coking facilities in the third quarter of 2002, HOVENSA reduced its last-in, first-out (LIFO) inventory of high sulfur crude oil. Consequently, HOVENSA recognized LIFO inventory cost in its cost of sales that is lower than the current cost. This reduced Amerada Hess Corporation’s share of HOVENSA’s loss by approximately $13 million.




Note 6 -		During the three- and nine-month periods ended September 30, 2002, the Corporation capitalized interest of $26 million and $75 million on major development projects ($14 million during the three- and nine-month periods ended September 30, 2001).

PART I — FINANCIAL INFORMATION (CONT’D.)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS


Note 7 -		The provision for income taxes consisted of the following (in millions):


		Three months					Nine months
		ended September 30					ended September 30

		2002			2001		2002			2001

Current		$	75		$	17	$	298		$	379




Deferred			(65	)		40		(70	)		99

	Total	$	10		$	57	$	228		$	478


Note 8 -		Foreign currency gains (losses), after income tax effects, amounted to the following (in millions):


	Three months					Nine months
	ended September 30					ended September 30

	2002		2001			2002		2001

Foreign currency gains (losses)	$	20	$	(13	)	$	8	$	—


Note 9 -		The weighted average number of common shares used in the basic and diluted earnings per share computations are as follows (in thousands):


	Three months				Nine months
	ended September 30				ended September 30

	2002		2001		2002		2001

Common shares — basic		88,328		88,133		88,116		88,116




Effect of dilutive securities




(equivalent shares)




Nonvested common stock		—		470		477		422




Stock options		—		593		491		523




Convertible preferred stock		—		205		205		205

Common shares — diluted		88,328		89,401		89,289		89,266

PART I — FINANCIAL INFORMATION (CONT’D.)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS


Note 10 -		Comprehensive income (loss) was as follows (in millions):


		Three months					Nine months
		ended September 30					ended September 30

		2002			2001		2002			2001

Net income (loss)		$	(136	)	$	167	$	153		$	860




FAS 133 transition adjustment			—			—		—			100




Net change in gain (loss) from hedging activities not recognized in net income (loss)			(100	)		113		(352	)		89




Change in foreign currency translation adjustment			(2	)		4		26			—

	Total comprehensive income (loss)	$	(238	)	$	284	$	(173	)	$	1,049


		The Corporation reclassifies hedging gains and losses included in other comprehensive income to earnings at the time the hedged transactions are recognized. Hedging results for exploration and production operations were approximately breakeven in the third quarter of 2002 and hedging increased earnings by $87 million ($133 million before taxes) in the first nine months of 2002. Hedging increased exploration and production results by $12 million ($19 million before taxes) and $6 million ($9 million before taxes) for the corresponding periods of 2001.








		At September 30, 2002, the after-tax deferred loss from crude oil and natural gas contracts used as exploration and production hedges and expiring through 2004 was approximately $94 million ($86 million of unrealized losses and $8 million of realized losses).








Note 11 -		The Corporation’s results by operating segment were as follows (in millions):


			Three months						Nine months
			ended September 30						ended September 30

			2002			2001			2002			2001

Operating revenues




	Exploration and production(*)		$	1,009		$	1,060		$	3,201		$	3,579




	Refining, marketing and shipping			1,962			2,015			5,888			7,664

		Total	$	2,971		$	3,075		$	9,089		$	11,243

Net income (loss)




	Exploration and production		$	(143	)	$	228		$	281		$	808




	Refining, marketing and shipping			70			5			65			210




	Corporate, including interest			(63	)		(66	)		(193	)		(158	)

		Total	$	(136	)	$	167		$	153		$	860

(*)

Includes transfers to affiliates of $153 million and $454 million during the three and nine months ended September 30, 2002, compared to $187 million and $712 million for the corresponding periods of 2001.

PART I — FINANCIAL INFORMATION (CONT’D.)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS


Note 12 -		The Financial Accounting Standards Board issued FAS No. 143,Accounting for Asset Retirement Obligations. This statement significantly changes the method of accruing costs associated with the retirement of fixed assets for which a legal retirement obligation exists, such as certain oil and gas production facilities. This standard becomes effective in 2003. The Corporation does not expect the effect of adopting the new accounting standard to be material to its income or financial position.

PART I — FINANCIAL INFORMATION (CONT’D.)

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

		Results of Operations

		Operating earnings, excluding special items, amounted to $121 million in the third quarter of 2002 compared with $167 million in the third quarter of 2001. Operating earnings for the first nine months of 2002 were $405 million compared with $860 million in the first nine months of 2001. There was a net loss of $136 million in the third quarter of 2002, including a charge for asset impairment and other special items. Net income was $153 million in the first nine months of 2002. The after-tax results by major operating activity for the three and nine months ended September 30, 2002 and 2001 were as follows (in millions, except per share data):


	Three months ended						Nine months ended
	September 30						September 30

	2002			2001			2002			2001

Exploration and production	$	181		$	228		$	578		$	808




Refining, marketing and shipping		3			5			20			210




Corporate		(23	)		(32	)		(56	)		(65	)




Interest expense		(40	)		(34	)		(137	)		(93	)

Operating earnings		121			167			405			860




Special items		(257	)		—			(252	)		—

Net income (loss)	$	(136	)	$	167		$	153		$	860

Net income (loss) per share	$	(1.54	)	$	1.86		$	1.72		$	9.63

		Exploration and Production

		Operating earnings from exploration and production activities decreased by $47 million and $230 million, respectively, in the third quarter and first nine months of 2002. The 2001 third quarter included income of $48 million from the resolution of a United Kingdom income tax dispute. Excluding the tax settlement, exploration and production earnings in the third quarter of each year were comparable. Results in the first nine months of 2002 were lower than the corresponding period of 2001 reflecting lower average crude oil and natural gas selling prices and higher unit costs, partially offset by increased production volumes.

PART I — FINANCIAL INFORMATION (CONT’D.)

		Results of Operations (Continued)

		The Corporation’s average selling prices, including the effects of hedging, were as follows:


		Three months ended				Nine months ended
		September 30				September 30

		2002		2001		2002		2001

Crude oil (per barrel)




	United States	$	26.19	$	23.38	$	24.33	$	24.15




	Foreign		26.25		24.62		24.91		26.02




Natural gas liquids (per barrel)




	United States	$	16.31	$	17.73	$	14.84	$	20.94




	Foreign		19.52		17.86		17.86		20.29




Natural gas (per Mcf)




	United States	$	3.40	$	3.42	$	3.45	$	4.39




	Foreign		2.17		1.96		2.17		2.51

The Corporation’s net daily worldwide production was as follows (in thousands):


			Three months ended				Nine months ended
			September 30				September 30

			2002		2001		2002		2001

Crude oil (barrels per day)




	United States			53		66		56		64




	United Kingdom			112		114		113		117




	Equatorial Guinea			39		9		39		3




	Norway			26		23		24		24




	Colombia			21		14		22		5




	Denmark			20		18		21		20




	Algeria			15		13		14		13




	Gabon			8		9		9		8




	Indonesia			4		6		5		6




	Azerbaijan			4		4		4		4

		Total		302		276		307		264

Natural gas liquids (barrels per day)




	United States			12		16		13		14




	Foreign			9		8		9		9

		Total		21		24		22		23

Natural gas (Mcf per day)




	United States			355		464		390		421




	United Kingdom			227		240		275		291




	Denmark			30		39		36		42




	Norway			28		24		25		25




	Indonesia, Thailand and other			63		30		42		31

		Total		703		797		768		810

Barrels of oil equivalent (barrels per day)				441		433		456		422

PART I — FINANCIAL INFORMATION (CONT’D.)

		Results of Operations (Continued)

		The Corporation’s oil and gas production, on a barrel-of-oil equivalent basis, increased by 2% in the third quarter and 8% in the first nine months of 2002 compared with the corresponding periods of 2001. The increase was primarily due to crude oil production from fields in Equatorial Guinea and Colombia acquired in August 2001, offset by lower United States crude oil and natural gas production, due principally to natural decline. The Corporation currently anticipates that 2003 crude oil and natural gas production will be lower than in 2002.

		Production expenses and depreciation, depletion and amortization charges were higher in the third quarter and first nine months of 2002, compared to the same periods of last year. The increases are due to higher production volumes and increased per barrel costs. Increased production expense per barrel principally reflects higher workover expense on several fields in the United States and North Sea. Per barrel depreciation, depletion and amortization charges reflect higher costs from production in Equatorial Guinea and certain Gulf of Mexico properties which were acquired in 2001 and have acquisition cost in their depletable base. The production from these properties has become a more significant portion of the Corporation’s total production in 2002. These per barrel expenses may continue to increase in 2003.

		Exploration expense was higher in the third quarter of 2002 compared with 2001 largely reflecting a $19 million expense for a prior year natural gas discovery in the United Kingdom, for which there are no current development plans. Exploration expense decreased in the first nine months of 2002 compared with 2001, while total spending for exploration drilling was comparable. The decrease was primarily due to improved exploration results.

		Foreign currency gains were $20 million in the third quarter of 2002 compared with a loss of $13 million in the third quarter of 2001. The gain largely reflects the strengthening of the U.S. dollar in relation to the Colombian peso. In the first nine months of 2002 foreign currency gains were $8 million compared with breakeven in the first nine months of 2001. This increase was due to a currency gain in Colombia, partially offset by a loss in the United Kingdom.

		Excluding the one-time deferred tax charge referred to below, the effective income tax rate on exploration and production earnings in the first nine months of 2002 was 40%, the same as in 2001. During the third quarter, the United Kingdom government enacted a 10% supplementary tax on profits from oil and gas production. A one-time charge of $43 million was recorded as a special item to increase the existing United Kingdom deferred tax liability on the balance sheet. In addition, the third quarter operating results include $23 million related to this tax increase. Nine million of the $23 million is the tax for the period from the retroactive effective date of April 17 through June 30 and $14 million is the tax on third quarter income.

PART I — FINANCIAL INFORMATION (CONT’D.)

		Results of Operations (Continued)

		Refining, Marketing and Shipping

		The operating earnings of refining and marketing activities amounted to income of $3 million in the third quarter of 2002 compared with income of $5 million in the corresponding period of 2001. For the first nine months of 2002, refining and marketing had income of $20 million compared with $210 million in 2001.

		HOVENSA

		The Corporation’s share of HOVENSA’s loss was $6 million in the third quarter of 2002 compared with income of $11 million in the third quarter of 2001. The Corporation’s share of HOVENSA’s loss in the first nine months of 2002 was $50 million compared with income of $77 million in 2001. Refining margins were depressed throughout the first nine months of 2002. In connection with the startup of the new coking facilities in the third quarter of 2002, HOVENSA reduced its last-in, first-out (LIFO) inventory of high sulfur crude oil. As a result, LIFO inventory cost was recognized in cost of sales that was lower than current cost. This reduced the Corporation’s share of HOVENSA’s loss by approximately $13 million. Income taxes on the Corporation’s share of HOVENSA’s results are not recorded due to available loss carryforwards.

		The Corporation’s share of HOVENSA’s crude runs amounted to 175,000 barrels per day in the first nine months of 2002 compared with 204,000 barrels per day in the first nine months of 2001, reflecting downtime at the fluid catalytic cracking unit and lower refining margins. The 58,000 barrel per day coker at HOVENSA is now fully operational.

		Operating earnings from refining and marketing activities also included interest income of $27 million in the first nine months of 2002 and $30 million in the first nine months of 2001 on the note received from PDVSA V.I. in connection with the formation of the joint venture.

		Effective October 2002, the Corporation agreed to surrender for cancellation the $125 million contingent note of PDVSA, V.I. issued to it in connection with the formation of HOVENSA. The cancellation of the contingent note was made in connection with the amendment of certain contracts relating to the HOVENSA joint venture, including a six-year extension of the contract for the supply of Mesa crude oil by an affiliate of Petroleos de Venezuela S.A. (“PDVSA”), an amendment to the pricing formula for the Merey crude oil supplied by an affiliate of PDVSA and an amendment to the services agreement between the Corporation and HOVENSA. The contingent note was not valued for accounting purposes and its cancellation will have no effect on the Corporation’s financial condition. In addition, in connection with the amendments to certain financing documents between HOVENSA and its lenders, the Corporation agreed to increase its obligation to provide funding to meet senior debt obligations from $15 million to $40 million until implementation of final low sulfur fuel regulations. After implementation, the Corporation’s support obligation will be reduced to $15 million.

PART I — FINANCIAL INFORMATION (CONT’D.)

		Results of Operations (Continued)

		Retail, energy marketing and other

		Results from retail gasoline operations were profitable in the third quarter and first nine months of 2002, but significantly lower than the corresponding periods of 2001, reflecting lower margins at gasoline stations. Energy marketing activities were slightly profitable in the third quarter of 2002 compared with a loss in the third quarter of 2001. Energy marketing results were also higher in the first nine months of 2002 compared with the same period last year. Results of the Port Reading refining facility in the third quarters of each year were comparable, but were lower in the first nine months of 2002, reflecting reduced refining margins.

		Total refined product sales volumes amounted to 103 million barrels in the first nine months of 2002 compared with 109 million barrels in the first nine months of 2001. The decrease was largely due to lower demand for distillates and residual fuel oils.

		The Corporation has a 50% voting interest in a consolidated partnership that trades energy commodities and energy derivatives. The Corporation also takes trading positions in addition to its hedging program. The Corporation’s after-tax results from trading activities, including its share of the earnings of the trading partnership, amounted to losses of $14 million in the third quarter and income of $4 million in the first nine months of 2002. Trading activities had income of $14 million in the third quarter and $26 million in the first nine months of 2001.

		Refining and marketing earnings will continue to be volatile reflecting competitive industry conditions and supply and demand factors, including the effects of weather.

		Corporate

		Net corporate expenses were $23 million in the third quarter and $56 million in the first nine months of 2002, compared to $32 million and $65 million in the same periods of 2001. The 2001 expenses include after-tax severance of $7 million and a contribution to the Twin Towers Fund of $3 million ($5 million before tax). There was also a higher provision for United States taxes on foreign source income in 2001. Pension expense increased in 2002.

		Interest

		After-tax interest increased to $40 million in the third quarter of 2002 compared with $34 million in the third quarter of 2001. In the first nine months of 2002, after-tax interest amounted to $137 million compared with $93 million in the same period of 2001. The change is due to increased borrowings related to acquisitions in 2001, partially offset by lower interest rates and higher amounts capitalized. Pre-tax capitalized interest amounted to $75 million in the first nine months of 2002 compared to $14 million in the corresponding period of 2001.

PART I — FINANCIAL INFORMATION (CONT’D.)

		Results of Operations (Continued)

		Special Items

		After-tax special items in the third quarter and first nine months of 2002 were as follows (in millions):


	Three months ended					Nine months ended
	September 30					September 30

	2002			2001		2002			2001

Asset impairment	$	(256	)	$	—	$	(256	)	$	—




Net gain from asset sales		42			—		69			—




Charge for increase in United Kingdom income tax rate		(43	)		—		(43	)		—




Reduction in carrying value of intangible assets		—			—		(14	)		—




Severance accrual		—			—		(8	)		—

	$	(257	)	$	—	$	(252	)	$	—

		In the third quarter of 2002, the Corporation recorded an after-tax impairment charge of $256 million to reduce the carrying value of certain producing oil and gas fields and exploration acreage in the Gulf of Mexico. The charge principally reflects reduced reserve estimates on these fields. The estimated reserve reduction is 29 million barrels of oil equivalent, or approximately 2% of proved reserves.

		In the third quarter, the Corporation completed the sale of six United States flag vessels for $161 million in cash and a note for $29 million. The sale resulted in a net gain of $67 million. The Corporation has agreed to support the buyer’s charter rate for these vessels for up to five years. A pre-tax gain of $50 million has been deferred as part of the sale transaction to reflect potential obligations under the support agreement. While the Corporation’s eventual obligations under the support agreement could exceed the amount of the deferred gain, based on current charter rates the amount recorded is considered adequate.

		In addition, several small oil and gas producing properties, principally in the United States, were sold for a loss of $25 million. The net gain from asset sales in the first nine months of 2002 included the sale of several small United Kingdom oil and gas fields and the Corporation’s United Kingdom energy marketing business. The pre-tax gain from asset sales of $103 million in the first nine months of 2002 is recorded in non-operating income in the income statement.

		As a result of the United Kingdom tax law change in the third quarter, the Corporation recorded a one-time charge of $43 million to increase the deferred tax liability on its balance sheet.

PART I — FINANCIAL INFORMATION (CONT’D.)

		Results of Operations (Continued)

		Consolidated Operating Revenues

		Sales and other operating revenues decreased by 2% in the third quarter and 18% in the first nine months of 2002, compared with the corresponding periods of 2001. The decrease in the third quarter primarily reflects the sale of the United Kingdom energy marketing business. The decrease in the first nine months of 2002 also reflects lower sales volumes of refined products and purchased natural gas related to U.S. energy marketing activities.

		Liquidity and Capital Resources

		Net cash provided by operating activities, including changes in operating assets and liabilities, amounted to $1,427 million in the first nine months of 2002 compared with $1,634 million in the first nine months of 2001. Excluding changes in balance sheet accounts, operating cash flow was $1,570 million in 2002 compared with $1,701 million in the first nine months of 2001.

		Total debt was $5,083 million at September 30, 2002 compared with $5,665 million at December 31, 2001. The Corporation’s debt to capitalization ratio decreased to 52.0% at September 30, 2002 compared with 53.6% at year-end. The Corporation expects to meet its debt reduction goal of $600 million for the year, including the purchase of $260 million of public debt in the first nine months of 2002.

		Loan agreement covenants allow the Corporation to borrow an additional $2,722 million for the construction or acquisition of assets at September 30, 2002. The Corporation has $1,495 million of additional borrowing capacity available under its revolving credit agreements and has additional unused lines of credit for $203 million under uncommitted arrangements with banks.

		In the first nine months of 2002, the Corporation sold United States flag vessels, its energy marketing business in the United Kingdom and several small oil and gas fields for net proceeds of $378 million. During the quarter, the Corporation entered into an agreement with Premier Oil PLC to exchange the Corporation’s 25% shareholding interest in Premier, plus $17 million in cash, for a 23% stake in Natuna Sea Block A in Indonesia. Completion of the transaction is conditional upon certain governmental consents. The Corporation does not expect a material income statement impact from this transaction. In addition, selected assets representing 5% to 10% of the Corporation’s crude oil and natural gas production are being considered for sale.

		The balances in accounts receivable, as well as accounts payable and accrued liabilities, are substantially lower at September 30, 2002 than at December 31, 2001. This decrease is largely due to the sale of the United Kingdom energy marketing business and the impact of lower selling prices and sales volumes on energy marketing activities in the United States.

PART I — FINANCIAL INFORMATION (CONT’D.)

		Liquidity and Capital Resources (Continued)

		The Corporation has increased cash contributions to its U.S. qualified pension plan in 2002. To date, $25 million has been contributed to the plan and a comparable amount is expected to be contributed by year-end or in early 2003. In addition to these two contributions, the Corporation expects to contribute approximately $50 million in 2003. Because of declines in equity markets and interest rates, the fair value of the Corporation’s pension plan assets is currently below the accumulated benefit obligation. If equity investment values do not significantly increase by the end of the year, the Corporation will record a non-cash charge of approximately $80 million, after-tax, to accumulated other comprehensive income in stockholders’ equity. The amount of the charge will vary based on changes in the fair value of pension assets and interest rates used to determine the present value of the accumulated benefits obligation.

		Following is a table showing aggregated information about certain contractual obligations at September 30, 2002 (in millions):


	Payments due by period

			Remainder		2003		2005
			of		and		and
	Total		2002		2004		2006		Thereafter

Short-term notes	$	3	$	3	$	—	$	—	$	—




Long-term debt, including capital leases		5,080		9		531		712		3,828




Operating leases		1,146		15		198		121		812

		The Corporation has entered into leveraged leases that are not included in the Corporation’s balance sheet, primarily related to retail gasoline stations. The rental commitments under these leases are included in the operating lease obligations shown in the above table. The net present value of the financings is approximately $425 million.

		None of the Corporation’s debt or lease obligations would be terminated, nor would principal or interest payments be accelerated, solely because of a credit rating downgrade to non-investment status. However, certain contracts with trading counterparties would require cash margin or collateral. The amount of potential additional margin fluctuates depending on trading volumes and market prices and, at September 30, 2002, it was approximately $150 million.

		The Corporation uses futures, forwards, options and swaps to reduce the effects of changes in the selling prices of crude oil, natural gas and refined products. These instruments fix the selling prices of a portion of the Corporation’s production and the related gains or losses are an integral part of the Corporation’s selling prices. The Corporation also uses derivatives in its energy marketing activities, generally to fix the purchase prices of energy products. At September 30, 2002, the Corporation had open hedge positions on 60% of its estimated worldwide crude oil production and 35% of its U.S. natural gas production for the remainder of the year. The Corporation has also hedged 70% of its estimated crude

PART I — FINANCIAL INFORMATION (CONT’D.)

		Liquidity and Capital Resources (Continued)

		oil production and 35% of its U.S. natural gas production for 2003 and 5% of its estimated crude oil production for 2004. The average price of WTI crude oil hedges is $25.25 for the remainder of 2002, $24.80 for 2003 and $24.05 for 2004. The average price of U.S. natural gas exploration and production hedges is $4.40 for the remainder of 2002 and $4.05 for 2003. In its energy marketing business, the Corporation has entered into fixed price sales contracts with deferred losses of $34 million, partially offset by financial instruments which fix the future purchase price. As market conditions change, the Corporation may adjust its hedge positions.

		The Corporation uses value at risk to estimate the potential effects of changes in fair values of derivatives and other instruments used in hedging activities and derivatives and commodities used in trading activities. Value at risk represents the maximum potential negative one-day change in fair value with 95% confidence. The Corporation estimates that at September 30, 2002, the value at risk was $62 million ($35 million at December 31, 2001) related to hedging activities and $10 million ($13 million at December 31, 2001) for trading activities.

		The Corporation’s trading activities consist of a consolidated trading partnership, in which the Corporation owns a 50% voting interest, and its proprietary trading accounts. Trading transactions are marked-to-market and are reflected in income currently. The information that follows represents 100% of the trading partnership and the Corporation’s proprietary accounts (in millions):


Fair value of unrealized positions at January 1, 2002	$	(58	)




Realized losses		59




Other changes in fair value		57

Fair value of unrealized positions at September 30, 2002	$	58

		Other changes in fair value reflect changes in market prices of existing positions and new positions added. There was no material change in fair value related to changes in valuation techniques and assumptions. After expenses and income taxes, the Corporation’s share of net trading income was $4 million in the first nine months of 2002.

		The table below summarizes the sources used in determining fair values for trading activities at September 30, 2002:


		Percentage of total fair
		value by year of maturity

Source of fair value		Total			2002			2003

Prices actively quoted			92	%		74	%		18	%




Other external sources			7			4			3




Internal estimates			1			1			—

	Total		100	%		79	%		21	%

PART I — FINANCIAL INFORMATION (CONT’D.)

		Liquidity and Capital Resources (Continued)

		The following table summarizes the fair values of net receivables relating to the Corporation’s trading activities and the credit rating of counterparties at September 30, 2002 (in millions):


Investment grade determined by outside sources		$	235




Investment grade determined internally*			66




Less than investment grade			32




Not determined			1

	Total	$	334

		* Based on information provided by counterparties and other available sources.

		The Corporation reduces its exposure to fluctuating foreign exchange rates by using forward contracts to fix the exchange rate on a portion of the foreign denominated liabilities of its North Sea operations. At September 30, 2002, the Corporation had $271 million of notional value foreign exchange contracts outstanding.

		During the first nine months of 2002, the Corporation made payments of $14 million relating to accrued severance liabilities established in connection with cost reduction initiatives in exploration and production and refining and marketing operations. An immaterial amount of accrued severance was reversed to income in the third quarter of 2002. The remaining severance balance is $15 million and will be paid primarily in the next twelve months.

		Capital expenditures in the first nine months of 2002 amounted to $1,207 million, of which $1,101 million related to exploration and production activities. Capital expenditures in the first nine months of 2001 amounted to $4,701 million, including the acquisition of Triton Energy Limited and the purchase of United States crude oil and natural gas reserves. Excluding acquisitions, capital expenditures in the first nine months of 2001 amounted to $1,116 million. For the remainder of 2002, capital expenditures are expected to be approximately $350 million and will be financed by internally generated funds. Capital expenditures for 2003 are expected to be approximately $1,750 million.

		Forward-Looking Information

		Certain sections of Management’s Discussion and Analysis of Results of Operations and Financial Condition, including references to the Corporation’s future results of operations and financial position, liquidity and capital resources, capital expenditures, oil and gas production, debt repayment and derivative disclosures, represent forward-looking information. Forward-looking disclosures are based on the Corporation’s current understanding and assessment of these activities and reasonable assumptions about the future. Actual results may differ from these disclosures because of changes in market conditions, government actions and other factors.

PART I — FINANCIAL INFORMATION (CONT’D.)

Item 3. Quantitative and Qualitative Disclosures About Market Risk

The information required by this item is presented under Item 2, “Management’s Discussion and Analysis of Results of Operations and Financial Condition.”

Item 4. Controls and Procedures

		Based upon their evaluation of the Corporation’s disclosure controls and procedures (as defined in Exchange Act Rules 13a - 14(c) and 15d - 14(c)) as of September 30, 2002, John B. Hess, Chief Executive Officer, and John Y. Schreyer, Chief Financial Officer, concluded that these disclosure controls and procedures were effective as of September 30, 2002.

		There have been no significant changes in the Corporation’s internal controls or in other factors that could significantly affect internal controls after September 30, 2002.

PART II — OTHER INFORMATION

Item 1. Legal Proceedings

		As reported in the Corporation’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2002, on July 22, the Corporation was served with a complaint filed in the U.S. District Court for the District of New Jersey alleging that sales of the Corporation’s common stock by 10 persons who are officers or former officers or directors violated federal securities laws. On August 5, the Corporation was served with a second complaint filed in the same court and making the same allegations. Each of these actions purports to be a class action.

		On September 10, a derivative complaint was filed in the Superior Court of the State of New Jersey in Middlesex County against all of the directors and certain officers and former officers and a former director alleging, among other grounds, breach of fiduciary duty in connection with sales of common stock of the Corporation by persons who are officers or former officers or directors of the Corporation. Two additional derivative complaints were filed in September in the same court and a third additional complaint was filed in October in New Jersey Superior Court in Mercer County against some or all of the same individuals also alleging, among other things, breach of fiduciary duty in connection with such sales.

		The Corporation believes that these actions are without merit and that they will have no material effect on the Corporation.

Item 6. Exhibits and Reports on Form 8-K

Exhibits


99(1)	-	Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.









99(2)	-	Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

	b.		Reports on Form 8-K

			During the three months ended September 30, 2002, Registrant filed the following reports on Form 8-K: i) a filing on August 8, 2002, reporting under Items 7 and 9 the filing of certifications of both John B. Hess, Chairman of the Board and Chief Executive Officer of the Registrant, and John Y. Schreyer, Executive Vice President and Chief Financial Officer of the Registrant, pursuant to the Commission’s Order No. 4-460, and ii) a filing on August 12, 2002, reporting under Item 5 the resignation of William R. Johnson as a member of the Registrant’s Board of Directors for personal reasons.

			On October 24, 2002, Registrant filed a report on Form 8-K reporting under Item 9 the prepared remarks of the Chairman of the Board of Registrant at a public conference call held on that date.

SIGNATURES

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


		AMERADA HESS CORPORATION (REGISTRANT)









		By		/s/ John B. Hess

				JOHN B. HESS CHAIRMAN OF THE BOARD AND CHIEF EXECUTIVE OFFICER









		By		/s/ John Y. Schreyer

				JOHN Y. SCHREYER EXECUTIVE VICE PRESIDENT AND CHIEF FINANCIAL OFFICER

Date: November 8, 2002

CERTIFICATIONS

I, John B. Hess, certify that:

1.		I have reviewed this quarterly report on Form 10-Q of Amerada Hess Corporation;

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

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

4.		The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

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

	b)		evaluated the effectiveness of the registrant’s disclosure controls and procedures as of a date within 90 days prior to the filing date of this quarterly report (the “Evaluation Date”); and

	c)		presented in this quarterly report our conclusions about the effectiveness of the disclosure controls and procedures based on our evaluation as of the Evaluation Date;

The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent function):

	a)		all significant deficiencies in the design or operation of internal controls which could adversely affect the registrant’s ability to record, process, summarize and report financial data and have identified for the registrant’s auditors any material weaknesses in internal controls; and

	b)		any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal controls; and

The registrant’s other certifying officers and I have indicated in this quarterly report whether or not there were significant changes in internal controls or in other factors that could significantly affect internal controls subsequent to the date of our most recent evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses.


		By		/s/ John B. Hess

				JOHN B. HESS CHAIRMAN OF THE BOARD AND CHIEF EXECUTIVE OFFICER

Date: November 8, 2002

I, John Y. Schreyer, certify that:

1.		I have reviewed this quarterly report on Form 10-Q of Amerada Hess Corporation;

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

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

4.		The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

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

	b)		evaluated the effectiveness of the registrant’s disclosure controls and procedures as of a date within 90 days prior to the filing date of this quarterly report (the “Evaluation Date”); and

	c)		presented in this quarterly report our conclusions about the effectiveness of the disclosure controls and procedures based on our evaluation as of the Evaluation Date;

	a)		all significant deficiencies in the design or operation of internal controls which could adversely affect the registrant’s ability to record, process, summarize and report financial data and have identified for the registrant’s auditors any material weaknesses in internal controls; and

	b)		any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal controls; and


		By		/s/ John Y. Schreyer

				JOHN Y. SCHREYER EXECUTIVE VICE PRESIDENT AND CHIEF FINANCIAL OFFICER

Date: November 8, 2002

Hess - 10-Q quarterly report FY

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