8-K

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Date of Report (Date of earliest event reported): November 5, 2009

_______________

EOG RESOURCES, INC.
(Exact name of registrant as specified in its charter)

Delaware (State or other jurisdiction of incorporation)	1-9743 (Commission File Number)	47-0684736 (I.R.S. Employer Identification No.)
1111 Bagby, Sky Lobby 2 Houston, Texas (Address of principal executive offices)		77002 (Zip code)

713-651-7000
(Registrant's telephone number, including area code)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

[ ] Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
[ ] Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
[ ] Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
[ ] Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

EOG RESOURCES, INC.

Item 2.02 Results of Operations and Financial Condition.

On November 5, 2009, EOG Resources, Inc. issued a press release announcing third quarter 2009 financial and operational results and fourth quarter and full year 2009 forecast and benchmark commodity pricing information (see Item 7.01 below). A copy of this release is attached as Exhibit 99.1 to this filing and is incorporated herein by reference. This information shall not be deemed to be "filed" for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of that section, and is not incorporated by reference into any filing under the Securities Act of 1933, as amended, or Securities Exchange Act of 1934, as amended.

Item 7.01 Regulation FD Disclosure.

Accompanying the press release announcing third quarter 2009 financial and operational results attached hereto as Exhibit 99.1 is fourth quarter and full year 2009 forecast and benchmark commodity pricing information for EOG Resources, Inc., which information is incorporated herein by reference. This information shall not be deemed to be "filed" for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of that section, and is not incorporated by reference into any filing under the Securities Act of 1933, as amended, or Securities Exchange Act of 1934, as amended.

Item 9.01 Financial Statements and Exhibits.

    (d)     Exhibits

                99.1     Press Release of EOG Resources, Inc. dated November 5, 2009 (including the accompanying fourth quarter and full year 2009 forecast and benchmark commodity pricing information).

SIGNATURES

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

		EOG RESOURCES, INC. (Registrant)
Date: November 5, 2009	By:	/s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Vice President and Chief Financial Officer (Principal Financial and Accounting Officer)

EXHIBIT INDEX

Exhibit No.                                 Description

99.1 Press Release of EOG Resources, Inc. dated November 5, 2009 (including the accompanying fourth quarter and full year 2009 forecast and benchmark commodity pricing information).

EX-99

	EXHIBIT 99.1
EOG Resources, Inc.
News Release
For Further Information Contact:	Investors
	Maire A. Baldwin
	(713) 651-6EOG (651-6364)
	Media and Investors
	Elizabeth M. Ivers
	(713) 651-7132

EOG RESOURCES REPORTS THIRD QUARTER 2009 RESULTS

• Increases 2009 Total Production Growth Target from 5.5 to 6 Percent and Total Liquids Growth Target from 25 to 27 Percent
• Sets 2010 Target of 13 Percent Total Production Growth and 50 Percent Total Liquids Growth
• Makes Another Tactical Acquisition in Fort Worth Barnett Combo and Announces Positive Drilling Results
• Reports New Core Area in East Texas Haynesville and Increases Acreage Position
• Discloses Seven High Rate Flow Tests in Horn River Basin

FOR IMMEDIATE RELEASE: Thursday, November 5, 2009

HOUSTON - EOG Resources, Inc. (EOG) today reported its third quarter 2009 operating and financial results. For the third quarter, EOG reported net income available to common stockholders of $4.2 million, or $0.02 per share. This compares to third quarter 2008 net income available to common stockholders of $1,556.3 million, or $6.20 per share.

The results for the third quarter 2009 included a previously disclosed $20.9 million ($13.4 million after tax, or $0.05 per share) net gain on the mark-to-market of financial commodity transactions. During the quarter, the net cash inflow related to financial commodity contracts was $331.2 million ($213.1 million after tax, or $0.84 per share). Consistent with some analysts' practice of matching realizations to settlement months, adjusted non-GAAP net income available to common stockholders for the quarter was $203.9 million, or $0.81 per share. Adjusted non-GAAP net income available to common stockholders for the third quarter 2008 was $588.3 million, or $2.34 per share. (Please refer to the attached tables for the reconciliation of adjusted non-GAAP net income available to common stockholders to GAAP net income available to common stockholders.)

Full Year 2009 and 2010 Production Growth Forecasts

Based on the performance of its North American liquids plays, EOG has increased its 2009 total company production growth target from 5.5 to 6 percent. For 2010, EOG has set a total company organic production growth target of 13 percent that includes total liquids production growth of 50 percent.

Operational Highlights and Targets

With recent well results from the North Dakota Bakken Core and Lite areas and the Fort Worth Barnett Shale Combo Play showing the impact of substantially more effective completions, EOG is increasing its total company liquids production growth estimate from 25 to 27 percent for 2009. Carrying this momentum into 2010, EOG plans to ramp up operations in these areas and, therefore, is raising its full year 2010 crude oil, condensate and natural gas liquids production growth target from 20 to 50 percent.

In addition, EOG announced a tactical acquisition of core Barnett Shale Combo assets in Montague and Cooke Counties, Texas with the addition of 7,800 net acres during the third quarter.

Two recent horizontal Combo wells, the Christian A #1H and B #1H, in which EOG has 100 percent working interest, were drilled in Cooke County. They began initial production at 1,000 and 600 barrels of oil per day (Bopd) with 2.5 and 2.0 million cubic feet per day (MMcfd) of natural gas, respectively. Reflecting the implementation of EOG's improved completion techniques, recent horizontal wells in eastern Montague and western Cooke Counties indicate estimated per well reserves of over 280,000 barrels of oil equivalent (Boe), net, an 80 percent improvement over EOG's early 2008 per well reserve estimates for the play. In the core area of the Combo where pay intervals are thickest, EOG has been developing its acreage by drilling vertical wells. EOG has 100 percent working interest in the Fitzgerald #1 and Stephenson #1, which reported initial production rates of 1,100 and 450 Bopd with 2.1 and 0.7 MMcfd, respectively. EOG expects to recover over 220,000 Boe, net from vertical wells d rilled in this core area.

EOG also reported positive well results from crude oil drilling activity in the North Dakota Bakken Core and Lite areas where it is operating a five-rig program. In the Bakken Core, EOG has 100 and 92 percent working interest, respectively, in the Fertile #9-8H and Fertile #13-18H. The wells commenced production at rates of 1,000 and 1,100 Bopd, respectively. In the Bakken Lite, EOG completed the Sidonia #2-5H and Ross #5-08H at initial rates of 626 and 750 Bopd, respectively. EOG has 78 and 100 percent working interest, respectively, in the wells. In addition, EOG drilled and tested its first wells in the Three Forks Formation to determine the extent of prospectivity across its acreage position. Initial results from the first two wells indicate encouraging pressure and flow rates in a portion of its acreage. By operating a 14-rig drilling program in North Dakota in 2010, EOG plans to focus on the Bakken Core and Lite, as well as further drilling and testing of the Three Forks F ormation.

"EOG is successfully transferring its technical expertise in drilling horizontal natural gas wells to unconventional oil and liquids rich reservoirs," said Mark G. Papa, Chairman and CEO. "Although it is late in the year, EOG is on track to target a higher liquids growth rate for 2009 because of the quality of wells that we are making in the Barnett Combo and Bakken Core and Lite. On the strength of the results from our unconventional liquids plays, we have the confidence to raise EOG's 2010 total company crude oil, condensate and natural gas liquids production growth target from 20 percent to 50 percent."

As one of the first operators to test the extension of the Haynesville Play further southwest into Nacogdoches and Shelby Counties, Texas, EOG reported initial production rates from three wells that equal the better wells drilled to date in the Louisiana core area. In Nacogdoches County, the Hill #1, Pop Pop Gas Unit #1 and Hassell Gas Unit #1, which were drilled early in the third quarter, began initial production at rates in excess of 15 MMcfd of natural gas. EOG has 42 percent working interest in the wells. Based on this confirmation and the results of the Gammage #1 exploration well drilled in Nacogdoches County, EOG has increased its acreage position in the play. Including the recent acquisition of approximately 37,000 net acres in Nacogdoches County, EOG now has 153,000 total net acres in the Haynesville Play, after adjusting for the expected exercise of third party preferential purchase rights.

In the Horn River Basin of British Columbia, EOG's summer program concentrated on the completion of seven natural gas wells drilled the previous winter. The wells had initial production rates ranging from 16 to 23 MMcfd. In addition, EOG reached agreement with the British Columbia government on royalty incentives for a significant portion of the company's acreage.

"This has been an especially dynamic quarter for EOG with considerable strides made on both the liquids and gas sides of our business," said Papa. "Although EOG rarely makes an acquisition, we added tactical parcels to two of our core plays - the Barnett Combo and Haynesville. I'm particularly pleased that our focus on horizontal unconventional oil is already yielding meaningful results."

Conference Call Scheduled for November 6, 2009

EOG's third quarter 2009 results conference call will be available via live audio webcast at 8 a.m. Central Standard Time (9 a.m. Eastern Standard Time) on Friday, November 6, 2009. To listen, log on to www.eogresources.com. The webcast will be archived on EOG's website through Friday, November 20, 2009.

EOG Resources, Inc. is one of the largest independent (non-integrated) oil and natural gas companies in the United States with proved reserves in the United States, Canada, Trinidad, the United Kingdom and China. EOG Resources, Inc. is listed on the New York Stock Exchange and is traded under the ticker symbol "EOG."

This press release (including the accompanying forecast and benchmark commodity pricing information) includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, including, among others, statements and projections regarding EOG's future financial position, operations, performance, business strategy, budgets, reserve information, levels of production and costs and statements regarding the plans and objectives of EOG's management for future operations, are forward-looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "goal," "may," "will" and "believe" or the negative of those terms or other variations or comparable terminology to identify its forward-looking statements. In particular, statements, express or implied, concerning EOG's future operating results and returns or EOG's ability to replace or increase reserves, increase production or generate income or cash flows are forward-looking statements. Forward-looking statements are not guarantees of performance. Although EOG believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that these assumptions are accurate or that these expectations will be achieved or will prove to have been correct. Moreover, EOG's forward-looking statements may be affected by known and unknown risks, events or circumstances that may be outside EOG's control. Important factors that could cause EOG's actual results to differ materially from the expectations reflected in EOG's forward-looking statements include, among others:

• the timing and extent of changes in prices for natural gas, crude oil and related commodities;

• changes in demand for natural gas, crude oil and related commodities, including ammonia and methanol;

• the extent to which EOG is successful in its efforts to discover, develop, market and produce reserves and to acquire natural gas and crude oil properties;

• the extent to which EOG can optimize reserve recovery and economically develop its plays utilizing horizontal and vertical drilling and advanced completion technologies;

• the extent to which EOG is successful in its efforts to economically develop its acreage in the Barnett Shale, the Bakken Formation, its Horn River Basin and Haynesville plays and its other exploration and development areas;

• EOG's ability to achieve anticipated production levels from existing and future natural gas and crude oil development projects, given the risks and uncertainties inherent in drilling, completing and operating natural gas and crude oil wells and the potential for interruptions of production, whether involuntary or intentional as a result of market or other conditions;

• the availability, proximity and capacity of, and costs associated with, gathering, processing, compression and transportation facilities;

• the availability, cost, terms and timing of issuance or execution of, and competition for, mineral licenses and leases and governmental and other permits and rights of way;

• competition in the oil and gas exploration and production industry for employees and other personnel, equipment, materials and services and, related thereto, the availability and cost of employees and other personnel, equipment, materials and services;

• EOG's ability to obtain access to surface locations for drilling and production facilities;

• the extent to which EOG's third-party-operated natural gas and crude oil properties are operated successfully and economically;

• EOG's ability to effectively integrate acquired natural gas and crude oil properties into its operations, fully identify existing and potential problems with respect to such properties and accurately estimate reserves, production and costs with respect to such properties;

• weather, including its impact on natural gas and crude oil demand, and weather-related delays in drilling and in the installation and operation of gathering and production facilities;

• the ability of EOG's customers and other contractual counterparties to satisfy their obligations to EOG and, related thereto, to access the credit and capital markets to obtain financing needed to satisfy their obligations to EOG;

• EOG's ability to access the commercial paper market and other credit and capital markets to obtain financing on terms it deems acceptable, if at all;

• the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise;

• the timing and extent of changes in foreign currency exchange rates, interest rates, inflation rates, global and domestic financial market conditions and global and domestic general economic conditions;

• the extent and effect of any hedging activities engaged in by EOG;

• the timing and impact of liquefied natural gas imports;

• the use of competing energy sources and the development of alternative energy sources;

• political developments around the world, including in the areas in which EOG operates;

• changes in government policies, legislation and regulations, including environmental regulations;

• the extent to which EOG incurs uninsured losses and liabilities;

• acts of war and terrorism and responses to these acts; and

• the other factors described under Item 1A, "Risk Factors," on pages 13 through 19 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2008 and any updates to those factors set forth in EOG's subsequent Quarterly Reports on Form 10-Q.

In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements may not occur, and you should not place any undue reliance on any of EOG's forward-looking statements. EOG's forward-looking statements speak only as of the date made and EOG undertakes no obligation to update or revise its forward-looking statements, whether as a result of new information, future events or otherwise.

The United States Securities and Exchange Commission (SEC) currently permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. As noted above, statements of proved reserves are only estimates and may be imprecise. Any reserve estimates provided in this press release that are not specifically designated as being estimates of proved reserves may include not only proved reserves, but also other categories of reserves that the SEC's guidelines strictly prohibit EOG from including in filings with the SEC. Investors are urged to consider closely the disclosure in EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2008, available from EOG at P.O. Box 4362, Houston, Texas 77210-4362 (Attn: Investor Relations). You can also obtain this report from the SEC by calling 1 - -800-SEC-0330 or from the SEC's website at www.sec.gov.

EOG RESOURCES, INC.
FINANCIAL REPORT
(Unaudited; in millions, except per share data)
			Three Months Ended				Nine Months Ended
			September 30,				September 30,
			2009		2008		2009		2008
Net Operating Revenues			$	1,006.8	$	3,263.9	$	3,026.1	$	5,493.4
Net Income Available to Common Stockholders			$	4.2	$	1,556.3	$	146.2	$	1,975.0
Net Income Per Share Available to Common Stockholders
	Basic		$	0.02	$	6.30	$	0.59	$	8.02
	Diluted		$	0.02	$	6.20	$	0.58	$	7.88
Average Number of Shares Outstanding
	Basic			249.5		247.2		248.6		246.3
	Diluted			252.4		250.9		251.3		250.8
SUMMARY INCOME STATEMENTS
(Unaudited; in thousands, except per share data)
			Three Months Ended				Nine Months Ended
			September 30,				September 30,
			2009		2008		2009		2008
Net Operating Revenues
	Natural Gas		$	450,304	$	1,259,130	$	1,477,926	$	3,637,325
	Crude Oil, Condensate and Natural Gas Liquids			398,806		574,402		886,268		1,494,043
	Gains on Mark-to-Market Commodity Derivative Contracts			20,877		1,381,733		405,830		69,067
	Gathering, Processing and Marketing			134,553		51,145		249,679		150,907
	Other, Net			2,309		(2,524)		6,394		142,074
		Total		1,006,849		3,263,886		3,026,097		5,493,416
Operating Expenses
	Lease and Well			142,183		142,238		422,288		396,294
	Transportation Costs			70,971		78,136		205,844		203,205
	Gathering and Processing Costs			13,318		9,104		44,552		26,385
	Exploration Costs			44,910		37,943		128,840		145,397
	Dry Hole Costs			3,016		12,849		39,653		28,062
	Impairments			69,404		32,142		181,921		113,591
	Marketing Costs			131,816		44,380		237,819		140,411
	Depreciation, Depletion and Amortization			385,330		346,247		1,150,251		958,740
	General and Administrative			62,775		70,893		179,481		185,459
	Taxes Other Than Income			47,823		97,771		118,715		279,866
		Total		971,546		871,703		2,709,364		2,477,410
Operating Income				35,303		2,392,183		316,733		3,016,006
Other Income (Expense), Net				(339)		13,864		2,637		28,756
Income Before Interest Expense and Income Taxes				34,964		2,406,047		319,370		3,044,762
Interest Expense, Net				30,407		12,095		73,594		33,315
Income Before Income Taxes				4,557		2,393,952		245,776		3,011,447
Income Tax Provision				361		837,667		99,576		1,036,000
Net Income				4,196		1,556,285		146,200		1,975,447
Preferred Stock Dividends				-		-		-		443
Net Income Available to Common Stockholders			$	4,196	$	1,556,285	$	146,200	$	1,975,004
Dividends Declared per Common Share			$	0.145	$	0.135	$	0.435	$	0.375

EOG RESOURCES, INC.
OPERATING HIGHLIGHTS
(Unaudited)
			Three Months Ended				Nine Months Ended
			September 30,				September 30,
			2009		2008		2009		2008
Wellhead Volumes and Prices
Natural Gas Volumes (MMcfd) (A)
	United States			1,128		1,196		1,153		1,141
	Canada			219		224		224		218
	Trinidad			268		240		266		229
	Other International (B)			13		19		15		16
		Total		1,628		1,679		1,658		1,604
Average Natural Gas Prices ($/Mcf) (C)
	United States		$	3.27	$	8.99	$	3.57	$	9.15
	Canada			3.15		8.15		3.67		8.33
	Trinidad			1.77		4.04		1.54		3.86
	Other International (B)			3.53		7.41		4.45		8.90
		Composite		3.01		8.15		3.27		8.28
Crude Oil and Condensate Volumes (MBbld) (A)
	United States			51.7		41.8		46.5		35.9
	Canada			4.7		3.0		3.6		2.7
	Trinidad			3.0		3.4		3.0		3.4
	Other International (B)			0.1		0.1		0.1		0.1
		Total		59.5		48.3		53.2		42.1
Average Crude Oil and Condensate Prices ($/Bbl) (C)
	United States		$	60.79	$	109.86	$	49.54	$	107.36
	Canada			61.43		109.71		51.91		104.57
	Trinidad			57.07		111.39		46.13		103.80
	Other International (B)			57.93		112.77		50.11		104.66
		Composite		60.65		109.96		49.51		106.89
Natural Gas Liquids Volumes (MBbld) (A)
	United States			23.1		13.2		22.2		14.7
	Canada			1.0		1.1		1.1		1.0
		Total		24.1		14.3		23.3		15.7
Average Natural Gas Liquids Prices ($/Bbl) (C)
	United States		$	31.15	$	69.79	$	26.42	$	63.08
	Canada			30.96		64.01		27.29		62.45
		Composite		31.14		69.33		26.46		63.04
Natural Gas Equivalent Volumes (MMcfed) (D)
	United States			1,577		1,525		1,566		1,445
	Canada			253		249		252		240
	Trinidad			286		261		284		250
	Other International (B)			13		20		15		16
		Total		2,129		2,055		2,117		1,951
Total Bcfe (D)				195.9		189.1		578.1		534.5
(A)	Million cubic feet per day or thousand barrels per day, as applicable.
(B)	Other International includes EOG's United Kingdom operations and, effective July 1, 2008, EOG's China operations.
(C)	Dollars per thousand cubic feet or per barrel, as applicable.
(D)	Million cubic feet equivalent per day or billion cubic feet equivalent, as applicable; includes natural gas, crude oil
	and condensate and natural gas liquids. Natural gas equivalents are determined using the ratio of 6.0 thousand
	cubic feet of natural gas to 1.0 barrel of crude oil and condensate or natural gas liquids.

	EOG RESOURCES, INC.
	SUMMARY BALANCE SHEETS
	(Unaudited; in thousands, except share data)
			September 30,		December 31,
			2009		2008
	ASSETS
Current Assets
	Cash and Cash Equivalents		$	608,511	$	331,311
	Accounts Receivable, Net			604,260		722,695
	Inventories			240,230		187,970
	Assets from Price Risk Management Activities			290,536		779,483
	Income Taxes Receivable			27,134		27,053
	Other			61,018		59,939
	Total			1,831,689		2,108,451
Property, Plant and Equipment
	Oil and Gas Properties (Successful Efforts Method)			23,515,362		20,803,629
	Other Property, Plant and Equipment			1,261,505		1,057,888
	Total Property, Plant and Equipment			24,776,867		21,861,517
	Less: Accumulated Depreciation, Depletion and Amortization			(9,524,312)		(8,204,215)
	Total Property, Plant and Equipment, Net			15,252,555		13,657,302
Other Assets				137,049		185,473
Total Assets			$	17,221,293	$	15,951,226
	LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
	Accounts Payable		$	783,764	$	1,122,209
	Accrued Taxes Payable			86,334		86,265
	Dividends Payable			36,255		33,461
	Liabilities from Price Risk Management Activities			16,370		4,429
	Deferred Income Taxes			114,304		368,231
	Current Portion of Long-Term Debt			37,000		37,000
	Other			127,124		113,321
	Total			1,201,151		1,764,916
Long-Term Debt				2,760,000		1,860,000
Other Liabilities				609,150		498,291
Deferred Income Taxes				3,133,252		2,813,522
Commitments and Contingencies
Stockholders' Equity
	Common Stock, $0.01 Par, 640,000,000 Shares Authorized:
		252,421,628 Shares Issued at September 30, 2009 and
		249,758,577 Shares Issued at December 31, 2008		202,524		202,498
	Additional Paid In Capital			528,544		323,805
	Accumulated Other Comprehensive Income			291,627		27,787
	Retained Earnings			8,502,940		8,466,143
	Common Stock Held in Treasury, 128,898 Shares at September 30, 2009
		and 126,911 Shares at December 31, 2008		(7,895)		(5,736)
		Total Stockholders' Equity		9,517,740		9,014,497
Total Liabilities and Stockholders' Equity			$	17,221,293	$	15,951,226

	EOG RESOURCES, INC.
	SUMMARY STATEMENTS OF CASH FLOWS
	(Unaudited; in thousands)
			Nine Months Ended
			September 30,
			2009		2008
Cash Flows from Operating Activities
Reconciliation of Net Income to Net Cash Provided by Operating Activities:
	Net Income		$	146,200	$	1,975,447
	Items Not Requiring (Providing) Cash
		Depreciation, Depletion and Amortization		1,150,251		958,740
		Impairments		181,921		113,591
		Stock-Based Compensation Expenses		74,532		76,344
		Deferred Income Taxes		39,793		790,699
		Other, Net		2,738		(135,325)
	Dry Hole Costs			39,653		28,062
	Mark-to-Market Commodity Derivative Contracts
		Total Gains		(405,830)		(69,067)
		Realized Gains (Losses)		986,980		(237,326)
	Other, Net			9,385		14,390
	Changes in Components of Working Capital and Other Assets and Liabilities
		Accounts Receivable		119,099		(219,947)
		Inventories		(23,592)		(45,354)
		Accounts Payable		(361,698)		221,449
		Accrued Taxes Payable		(17,955)		135,747
		Other Assets		(4,255)		(18,756)
		Other Liabilities		9,357		(3,397)
	Changes in Components of Working Capital Associated with
	Investing and Financing Activities			147,097		14,389
Net Cash Provided by Operating Activities				2,093,676		3,599,686
Investing Cash Flows
	Additions to Oil and Gas Properties			(2,267,884)		(3,532,343)
	Additions to Other Property, Plant and Equipment			(240,614)		(320,699)
	Proceeds from Sales of Assets			2,515		369,669
	Changes in Components of Working Capital Associated with
	Investing Activities			(146,783)		(14,501)
	Other, Net			1,405		(1,316)
Net Cash Used in Investing Activities				(2,651,361)		(3,499,190)
Financing Cash Flows
	Long-Term Debt Borrowings			900,000		750,000
	Long-Term Debt Repayments			-		(38,000)
	Dividends Paid			(105,989)		(81,453)
	Redemption of Preferred Stock			-		(5,395)
	Excess Tax Benefits from Stock-Based Compensation			34,052		69,824
	Treasury Stock Purchased			(9,888)		(11,266)
	Proceeds from Stock Options Exercised and Employee Stock Purchase Plan			13,691		67,414
	Debt Issuance Costs			(8,887)		(6,704)
	Other, Net			(314)		112
Net Cash Provided by Financing Activities				822,665		744,532
Effect of Exchange Rate Changes on Cash				12,220		(13,282)
Increase in Cash and Cash Equivalents				277,200		831,746
Cash and Cash Equivalents at Beginning of Period				331,311		54,231
Cash and Cash Equivalents at End of Period			$	608,511	$	885,977

EOG RESOURCES, INC.
QUANTITATIVE RECONCILIATION OF ADJUSTED NET INCOME AVAILABLE TO COMMON STOCKHOLDERS (Non-GAAP)
TO NET INCOME AVAILABLE TO COMMON STOCKHOLDERS (GAAP)
(Unaudited; in thousands, except per share data)
The following chart adjusts three-month and nine-month periods ended September 30, 2009 and 2008 reported Net Income Available to Common Stockholders (GAAP) to reflect actual net cash realized from financial commodity price transactions by eliminating the unrealized mark-to-market (gains) losses from these transactions and to eliminate the gain on the sale of EOG's Appalachian assets in the first quarter of 2008. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings to match realizations to production settlement months and make certain other adjustments to exclude one-time items. EOG management uses this information for comparative purposes within the industry.
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2009		2008		2009		2008
Reported Net Income Available to Common Stockholders (GAAP)		$	4,196	$	1,556,285	$	146,200	$	1,975,004
Mark-to-Market (MTM) Commodity Derivative Contracts Impact
	Total Gains		(20,877)		(1,381,733)		(405,830)		(69,067)
	Realized Gains (Losses)		331,240		(122,467)		986,980		(237,326)
	Subtotal		310,363		(1,504,200)		581,150		(306,393)
	After Tax MTM Impact		199,719		(967,953)		373,970		(197,164)
Less: Gain on Sale of Appalachian Assets, Net of Tax			-		-		-		(84,748)
Adjusted Net Income Available to Common Stockholders (Non-GAAP)		$	203,915	$	588,332	$	520,170	$	1,693,092
Net Income Per Share Available to Common Stockholders (GAAP)
	Basic	$	0.02	$	6.30	$	0.59	$	8.02
	Diluted	$	0.02	$	6.20	$	0.58	$	7.88
Adjusted Net Income Per Share Available to Common Stockholders    (Non-GAAP)
	Basic	$	0.82	$	2.38	$	2.09	$	6.87
	Diluted	$	0.81	$	2.34	$	2.07	$	6.75
Average Number of Shares
	Basic		249,535		247,155		248,647		246,343
	Diluted		252,422		250,930		251,288		250,765

EOG RESOURCES, INC.
QUANTITATIVE RECONCILIATION OF DISCRETIONARY CASH FLOW
AVAILABLE TO COMMON STOCKHOLDERS (Non-GAAP)
TO NET CASH PROVIDED BY OPERATING ACTIVITIES (GAAP)
(Unaudited; in thousands)
The following chart reconciles three-month and nine-month periods ended September 30, 2009 and 2008 Net Cash Provided by Operating Activities (GAAP) to Discretionary Cash Flow Available to Common Stockholders (Non-GAAP). EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust Net Cash Provided by Operating Activities for Exploration Costs (excluding Stock-Based Compensation Expenses), Changes in Components of Working Capital and Other Assets and Liabilities, Changes in Components of Working Capital Associated with Investing and Financing Activities and Preferred Stock Dividends. EOG management uses this information for comparative purposes within the industry.
			Three Months				Nine Months
			Ended September 30,				Ended September 30,
			2009		2008		2009		2008
Net Cash Provided by Operating Activities (GAAP)			$	816,458	$	1,537,065	$	2,093,676	$	3,599,686
Adjustments
	Exploration Costs (excluding Stock-Based Compensation Expenses)			39,814		32,818		113,644		131,909
	Changes in Components of Working Capital and Other Assets and Liabilities
		Accounts Receivable		29,922		(175,579)		(119,099)		219,947
		Inventories		1,441		36,178		23,592		45,354
		Accounts Payable		(53,125)		34,046		361,698		(221,449)
		Accrued Taxes Payable		212		(228,485)		17,955		(135,747)
		Other Assets		(3,232)		(42,867)		4,255		18,756
		Other Liabilities		(34,199)		(5,043)		(9,357)		3,397
	Changes in Components of Working Capital Associated
		with Investing and Financing Activities		22,086		(15,164)		(147,097)		(14,389)
	Preferred Stock Dividends			-		-		-		(443)
Discretionary Cash Flow Available to Common Stockholders (Non-GAAP)			$	819,377	$	1,172,969	$	2,339,267	$	3,647,021

EOG RESOURCES, INC.
FOURTH QUARTER AND FULL YEAR 2009 FORECAST AND BENCHMARK COMMODITY PRICING
(a) Fourth Quarter and Full Year 2009 Forecast The forecast items for the fourth quarter and full year 2009 set forth below for EOG Resources, Inc. (EOG) are based on current available information and expectations as of the date of the accompanying press release. This forecast replaces and supersedes any previously issued guidance or forecast. (b) Benchmark Commodity Pricing EOG bases United States and Canada natural gas price differentials upon the natural gas price at Henry Hub, Louisiana using the simple average of the NYMEX settlement prices for the last three trading days of the applicable month. EOG bases United States, Canada and Trinidad crude oil and condensate price differentials upon the West Texas Intermediate crude oil price at Cushing, Oklahoma using the simple average of the NYMEX settlement prices for each trading day within the applicable calendar month.
						ESTIMATED RANGES
						(Unaudited)
				4Q 2009				Full Year 2009
Daily Production
	Natural Gas (MMcfd)
			United States	1,075	-	1,115		1,132	-	1,145
			Canada	210	-	230		221	-	226
			Trinidad	240	-	260		260	-	264
			Other International	10	-	15		13	-	15
			Total	1,535	-	1,620		1,626	-	1,650
	Crude Oil and Condensate (MBbld)
			United States	49.0	-	52.0		47.0	-	48.0
			Canada	4.8	-	6.8		4.0	-	4.4
			Trinidad	2.8	-	3.2		2.9	-	3.1
			Total	56.6	-	62.0		53.9	-	55.5
	Natural Gas Liquids (MBbld)
			United States	21.0	-	26.0		22.0	-	23.2
			Canada	0.7	-	1.0		0.9	-	1.1
			Total	21.7	-	27.0		22.9	-	24.3
	Natural Gas Equivalent Volumes (MMcfed)
			United States	1,495	-	1,583		1,546	-	1,572
			Canada	243	-	277		250	-	259
			Trinidad	257	-	279		278	-	283
			Other International	10	-	15		13	-	15
			Total	2,005	-	2,154		2,087	-	2,129
						ESTIMATED RANGES
						(Unaudited)
Operating Costs				4Q 2009				Full Year 2009
	Unit Costs ($/Mcfe)
			Lease and Well	$ 0.73	-	$ 0.77		$ 0.73	-	$ 0.76
			Transportation Costs	$ 0.33	-	$ 0.37		$ 0.35	-	$ 0.37
			Depreciation, Depletion and Amortization	$ 2.01	-	$ 2.06		$ 1.99	-	$ 2.03
Expenses ($MM)
	Exploration, Dry Hole and Impairment			$ 150.0	-	$ 170.0		$ 500.0	-	$ 520.0
	General and Administrative			$   60.0		$   64.0		$ 238.5		$ 244.5
	Gathering and Processing			$   16.0	-	$   20.0		$   61.0	-	$   67.0
	Capitalized Interest			$   13.0	-	$   15.0		$   50.5	-	$   54.0
	Net Interest			$   28.0	-	$   32.0		$   98.0	-	$ 110.0
Taxes Other Than Income (% of Revenue)				5.5%	-	7.0%		5.1%	-	5.6%
Income Taxes
	Effective Rate			30%	-	40%		35%	-	45%
	Current Taxes ($MM)			$ 10	-	$ 20		$ 65	-	$ 85
Capital Expenditures ($MM) - FY 2009
	Exploration and Development, excluding Acquisitions						Approximately			$ 3,100
	Gathering, Processing and Other						Approximately			$    300
	Acquisitions						Approximately			$    320
Pricing - (Refer to Benchmark Commodity Pricing in text)
	Natural Gas ($/Mcf)
		Differentials (include the effect of physical contracts)
			United States - below NYMEX Henry Hub	$ 0.15	-	$ 0.35		$ 0.33	-	$ 0.38
			Canada - below NYMEX Henry Hub	$ 0.20	-	$ 0.40		$ 0.25	-	$ 0.35
		Realizations
			Trinidad	$ 1.50	-	$ 2.50		$ 1.50	-	$ 1.75
			Other International	$ 3.75	-	$ 5.25		$ 4.20	-	$ 4.60
	Crude Oil and Condensate ($/Bbl)
		Differentials
			United States - below WTI	$ 9.50	-	$ 13.00		$   8.00	-	$   9.00
			Canada - below WTI	$ 6.00	-	$ 10.00		$   4.40	-	$   5.00
			Trinidad - below WTI	$ 8.75	-	$ 12.75		$ 10.50	-	$ 11.50
Definitions
	$/Bbl		U.S. Dollars per barrel
	$/Mcf		U.S. Dollars per thousand cubic feet
	$/Mcfe		U.S. Dollars per thousand cubic feet equivalent
	$MM		U.S. Dollars in millions
	MBbld		Thousand barrels per day
	MMcfd		Million cubic feet per day
	MMcfed		Million cubic feet equivalent per day
	NYMEX		New York Mercantile Exchange
	WTI		West Texas Intermediate