Oil and Gas Exploration and Production Industries Disclosures (Tables)

12 Months Ended

Dec. 31, 2012

Oil and Gas Exploration and Production Industries Disclosures [Abstract]

Net Proved and Proved Developed Oil and Gas Reserve Quantities [Table Text Block]

The following tables set forth EOG's net proved and proved developed reserves at December 31 for each of the four years in the period ended December 31, 2012, and the changes in the net proved reserves for each of the three years in the period ended December 31, 2012, as estimated by the Engineering and Acquisitions Department of EOG:

NET PROVED AND PROVED DEVELOPED RESERVE SUMMARY

		United			Other
		States	Canada	Trinidad	International (1)	Total
NET PROVED RESERVES
Crude Oil (MBbl) (2)
Net proved reserves at December 31, 2009		188,452	25,586	5,443	58	219,539
	Revisions of previous estimates	(8,313)	(104)	(754)	20	(9,151)
	Purchases in place	13	-	-	-	13
	Extensions, discoveries and other additions	199,479	3,198	1,751	48	204,476
	Sales in place	(1,082)	(589)	-	-	(1,671)
	Production	(23,092)	(2,455)	(1,709)	(28)	(27,284)
Net proved reserves at December 31, 2010		355,457	25,636	4,731	98	385,922
	Revisions of previous estimates	(21,188)	(4,611)	18	25	(25,756)
	Purchases in place	9	-	-	-	9
	Extensions, discoveries and other additions	202,552	449	-	-	203,001
	Sales in place	(4,301)	-	-	-	(4,301)
	Production	(37,233)	(2,882)	(1,242)	(25)	(41,382)
Net proved reserves at December 31, 2011		495,296	18,592	3,507	98	517,493
	Revisions of previous estimates	4,105	(2,493)	71	5	1,688
	Purchases in place	1,010	-	-	-	1,010
	Extensions, discoveries and other additions	241,171	5,681	-	8,834	255,686
	Sales in place	(15,921)	(1,343)	-	-	(17,264)
	Production	(54,632)	(2,574)	(550)	(39)	(57,795)
Net proved reserves at December 31, 2012		671,029	17,863	3,028	8,898	700,818
Natural Gas Liquids (MBbl) (2)
Net proved reserves at December 31, 2009		91,489	1,972	-	-	93,461
	Revisions of previous estimates	27,490	(196)	-	-	27,294
	Purchases in place	-	-	-	-	-
	Extensions, discoveries and other additions	42,221	21	-	-	42,242
	Sales in place	(2)	(6)	-	-	(8)
	Production	(10,764)	(316)	-	-	(11,080)
Net proved reserves at December 31, 2010		150,434	1,475	-	-	151,909
	Revisions of previous estimates	35,999	43	-	-	36,042
	Purchases in place	17	-	-	-	17
	Extensions, discoveries and other additions	65,288	-	-	-	65,288
	Sales in place	(10,008)	-	-	-	(10,008)
	Production	(15,144)	(316)	-	-	(15,460)
Net proved reserves at December 31, 2011		226,586	1,202	-	-	227,788
	Revisions of previous estimates	47,293	563	-	-	47,856
	Purchases in place	612	-	-	-	612
	Extensions, discoveries and other additions	71,396	178	-	-	71,574
	Sales in place	(7,300)	(77)	-	-	(7,377)
	Production	(20,181)	(309)	-	-	(20,490)
Net proved reserves at December 31, 2012		318,406	1,557	-	-	319,963

EOG RESOURCES, INC.

SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

		United			Other
		States	Canada	Trinidad	International (1)	Total
Natural Gas (Bcf) (3)
Net proved reserves at December 31, 2009		6,350.1	1,549.5	985.8	12.7	8,898.1
	Revisions of previous estimates	(222.7)	(29.9)	(88.6)	1.9	(339.3)
	Purchases in place	-	-	-	-	-
	Extensions, discoveries and other additions	821.3	3.4	63.0	7.9	895.6
	Sales in place	(34.6)	(316.2)	-	-	(350.8)
	Production	(422.6)	(73.0)	(132.6)	(5.2)	(633.4)
Net proved reserves at December 31, 2010		6,491.5	1,133.8	827.6	17.3	8,470.2
	Revisions of previous estimates	(344.0)	(49.8)	(24.2)	1.3	(416.7)
	Purchases in place	3.0	-	-	-	3.0
	Extensions, discoveries and other additions	634.6	-	74.7	4.5	713.8
	Sales in place	(323.6)	-	-	-	(323.6)
	Production	(415.7)	(48.1)	(127.4)	(4.6)	(595.8)
Net proved reserves at December 31, 2011		6,045.8	1,035.9	750.7	18.5	7,850.9
	Revisions of previous estimates	(1,736.0)	(894.5)	(24.1)	1.6	(2,653.0)
	Purchases in place	14.8	-	-	-	14.8
	Extensions, discoveries and other additions	477.8	-	-	0.3	478.1
	Sales in place	(386.2)	(8.5)	-	-	(394.7)
	Production	(380.2)	(34.6)	(138.4)	(3.4)	(556.6)
Net proved reserves at December 31, 2012		4,036.0	98.3	588.2	17.0	4,739.5
Oil Equivalents (MBoe) (2)
Net proved reserves at December 31, 2009		1,338,292	285,808	169,747	2,172	1,796,019
	Revisions of previous estimates	(17,945)	(5,288)	(15,513)	342	(38,404)
	Purchases in place	14	-	-	-	14
	Extensions, discoveries and other additions	378,582	3,789	12,250	1,363	395,984
	Sales in place	(6,860)	(53,288)	-	-	(60,148)
	Production	(104,277)	(14,937)	(23,815)	(901)	(143,930)
Net proved reserves at December 31, 2010		1,587,806	216,084	142,669	2,976	1,949,535
	Revisions of previous estimates	(42,526)	(12,865)	(4,011)	239	(59,163)
	Purchases in place	521	-	-	-	521
	Extensions, discoveries and other additions	373,602	448	12,455	750	387,255
	Sales in place	(68,247)	-	-	-	(68,247)
	Production	(121,648)	(11,219)	(22,484)	(787)	(156,138)
Net proved reserves at December 31, 2011		1,729,508	192,448	128,629	3,178	2,053,763
	Revisions of previous estimates	(237,936)	(151,015)	(3,953)	283	(392,621)
	Purchases in place	4,098	-	-	-	4,098
	Extensions, discoveries and other additions	392,196	5,860	-	8,876	406,932
	Sales in place	(87,588)	(2,832)	-	-	(90,420)
	Production	(138,170)	(8,657)	(23,616)	(611)	(171,054)
Net proved reserves at December 31, 2012		1,662,108	35,804	101,060	11,726	1,810,698

(1) Other International includes EOG's United Kingdom, China and Argentina operations.

(2) Thousand barrels or thousand barrels of oil equivalent, as applicable; oil equivalents include crude oil and condensate, NGLs and natural gas.  Oil equivalents are determined using the ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas.

(3) Billion cubic feet.

Net Proved Developed and Net Proved Undeveloped Oil and Gas Reserve Quantities [Table Text Block]

		United			Other
		States	Canada	Trinidad	International (1)	Total
NET PROVED DEVELOPED RESERVES
Liquids (MBbl)
	December 31, 2009	189,322	10,831	3,966	58	204,177
	December 31, 2010	253,308	12,758	3,853	98	270,017
	December 31, 2011	338,144	9,220	2,657	97	350,118
	December 31, 2012	442,648	7,963	2,378	253	453,242
Natural Gas (Bcf)
	December 31, 2009	3,330.1	681.0	609.4	12.7	4,633.2
	December 31, 2010	3,519.7	401.6	519.2	17.3	4,457.8
	December 31, 2011	3,234.9	295.8	606.3	18.6	4,155.6
	December 31, 2012	2,387.5	98.3	476.7	17.0	2,979.5
Oil Equivalents (MBoe)
	December 31, 2009	744,339	124,323	105,540	2,172	976,374
	December 31, 2010	839,928	79,701	90,382	2,976	1,012,987
	December 31, 2011	877,301	58,524	103,710	3,178	1,042,713
	December 31, 2012	840,564	24,348	81,826	3,081	949,819
NET PROVED UNDEVELOPED RESERVES
Liquids (MBbl)
	December 31, 2009	90,619	16,727	1,477	-	108,823
	December 31, 2010	252,583	14,352	879	-	267,814
	December 31, 2011	383,739	10,574	850	-	395,163
	December 31, 2012	546,786	11,456	651	8,645	567,538
Natural Gas (Bcf)
	December 31, 2009	3,020.0	868.5	376.4	-	4,264.9
	December 31, 2010	2,971.7	732.2	308.5	-	4,012.4
	December 31, 2011	2,810.8	740.1	144.4	-	3,695.3
	December 31, 2012	1,648.5	-	111.5	-	1,760.0
Oil Equivalents (MBoe)
	December 31, 2009	593,953	161,486	64,207	-	819,646
	December 31, 2010	747,878	136,383	52,287	-	936,548
	December 31, 2011	852,207	133,924	24,919	-	1,011,050
	December 31, 2012	821,544	11,456	19,234	8,645	860,879

(1) Other International includes EOG's United Kingdom, China and Argentina operations.

Capitalized Costs Relating to Oil an d Gas Producing Activities

Capitalized Costs Relating to Oil and Gas Producing Activities.  The following table sets forth the capitalized costs relating to EOG's crude oil and natural gas producing activities at December 31, 2012 and 2011:

			2012		2011
Proved properties		$	36,872,434	$	32,353,380
Unproved properties			1,253,864		1,311,055
	Total		38,126,298		33,664,435
Accumulated depreciation, depletion and amortization			(16,849,068)		(13,981,143)
	Net capitalized costs	$	21,277,230	$	19,683,292

Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities

The following table sets forth costs incurred related to EOG's oil and gas activities for the years ended December 31, 2012, 2011 and 2010:

				United						Other
				States		Canada		Trinidad		International (1)		Total
2012
Acquisition Costs of Properties
	Unproved		$	471,345	$	33,561	$	1,000	$	(603)	$	505,303
	Proved			739		-		-		-		739
		Subtotal		472,084		33,561		1,000		(603)		506,042
Exploration Costs				333,534		38,530		19,555		53,979		445,598
Development Costs (2)				5,657,378		278,995		32,609		147,568		6,116,550
		Total	$	6,462,996	$	351,086	$	53,164	$	200,944	$	7,068,190
2011
Acquisition Costs of Properties
	Unproved		$	295,160	$	6,216	$	-	$	(604)	$	300,772
	Proved			4,219		28		-		-		4,247
		Subtotal		299,379		6,244		-		(604)		305,019
Exploration Costs				311,369		31,472		2,549		18,164		363,554
Development Costs (3)				5,410,378		302,564		138,905		78,744		5,930,591
		Total	$	6,021,126	$	340,280	$	141,454	$	96,304	$	6,599,164
2010
Acquisition Costs of Properties
	Unproved		$	403,509	$	13,956	$	-	$	(107)	$	417,358
	Proved			-		-		-		-		-
		Subtotal		403,509		13,956		-		(107)		417,358
Exploration Costs				454,379		38,604		23,386		86,784		603,153
Development Costs (4)				3,892,403		417,176		114,986		13,429		4,437,994
		Total	$	4,750,291	$	469,736	$	138,372	$	100,106	$	5,458,505

(1) Other International primarily consists of EOG's United Kingdom, China and Argentina operations.

(2) Includes Asset Retirement Costs of $80 million, $33 million, $2 million and $12 million for the United States, Canada, Trinidad and Other International, respectively.  Excludes other property, plant and equipment.

(3) Includes Asset Retirement Costs of $52 million, $70 million, $7 million and $4 million for the United States, Canada, Trinidad and Other International, respectively.  Excludes other property, plant and equipment.

(4) Includes Asset Retirement Costs of $71 million, $2 million, $(3) million and $2 million for the United States, Canada, Trinidad and Other International, respectively.  Excludes other property, plant and equipment.

Results of Operations for Oil and Gas Producing Activities

Results of Operations for Oil and Gas Producing Activities ⁽¹⁾.  The following table sets forth results of operations for oil and gas producing activities for the years ended December 31, 2012, 2011 and 2010:

			United						Other
			States		Canada		Trinidad		International (2)		Total
2012
Crude Oil and Condensate, Natural Gas Liquids and Natural Gas Revenues		$	7,048,572	$	321,597	$	565,030	$	23,177	$	7,958,376
Other			40,780		367		15		-		41,162
	Total		7,089,352		321,964		565,045		23,177	`	7,999,538
Exploration Costs			162,152		13,350		2,262		7,805		185,569
Dry Hole Costs			1,772		1,570		-		11,628		14,970
Transportation Costs			591,547		7,511		1,104		1,269		601,431
Production Costs			1,264,633		154,509		37,792		11,694		1,468,628
Impairments			294,172		976,563		-		-		1,270,735
Depreciation, Depletion and Amortization			2,637,500		222,366		146,690		17,958		3,024,514
Income (Loss) Before Income Taxes			2,137,576		(1,053,905)		377,197		(27,177)		1,433,691
Income Tax Provision (Benefit)			761,459		(136,105)		119,442		(21,890)		722,906
Results of Operations		$	1,376,117	$	(917,800)	$	257,755	$	(5,287)	$	710,785
2011
Crude Oil and Condensate, Natural Gas Liquids and Natural Gas Revenues		$	5,814,942	$	459,853	$	555,143	$	28,250	$	6,858,188
Other			32,329		258		586		-		33,173
	Total		5,847,271		460,111		555,729		28,250	`	6,891,361
Exploration Costs			148,199		10,479		2,520		10,460		171,658
Dry Hole Costs			30,521		432		-		22,277		53,230
Transportation Costs			421,060		5,969		1,620		1,673		430,322
Production Costs			1,096,955		174,973		49,318		10,964		1,332,210
Impairments			575,976		452,103		-		2,958		1,031,037
Depreciation, Depletion and Amortization			2,011,080		258,772		106,802		17,160		2,393,814
Income (Loss) Before Income Taxes			1,563,480		(442,617)		395,469		(37,242)		1,479,090
Income Tax Provision (Benefit)			569,153		(121,044)		202,815		(13,056)		637,868
Results of Operations		$	994,327	$	(321,573)	$	192,654	$	(24,186)	$	841,222
2010
Crude Oil and Condensate, Natural Gas Liquids and Natural Gas Revenues		$	3,928,240	$	477,416	$	447,852	$	27,707	$	4,881,215
Other			19,886		(31)		3,696		-		23,551
	Total		3,948,126		477,385		451,548		27,707		4,904,766
Exploration Costs			156,252		17,597		2,277		11,255		187,381
Dry Hole Costs			30,927		14,875		5,000		21,684		72,486
Transportation Costs			372,466		9,892		1,348		1,483		385,189
Production Costs			763,769		174,667		51,125		8,504		998,065
Impairments			271,466		451,703		1,465		418		725,052
Depreciation, Depletion and Amortization			1,430,408		314,663		70,553		15,399		1,831,023
Income (Loss) Before Income Taxes			922,838		(506,012)		319,780		(31,036)		705,570
Income Tax Provision (Benefit)			375,855		(151,315)		140,413		(14,245)		350,708
Results of Operations		$	546,983	$	(354,697)	$	179,367	$	(16,791)	$	354,862

(1) Excludes gains or losses on the mark-to-market of financial commodity derivative contracts, gains or losses on sales of reserves and related assets, interest charges and general corporate expenses for each of the three years in the period ended December 31, 2012.

(2) Other International primarily consists of EOG's United Kingdom, China and Argentina operations.

Production Costs Per Barrel of Oil Equivalent

The following table sets forth production costs per barrel of oil equivalent, excluding severance/production and ad valorem taxes, for the years ended December 31, 2012, 2011 and 2010:

		United						Other
		States		Canada		Trinidad		International (1)		Composite
Year Ended December 31, 2012	$	5.96	$	16.42	$	0.98	$	18.97	$	5.85
Year Ended December 31, 2011	$	6.19	$	14.26	$	0.78	$	13.82	$	6.03
Year Ended December 31, 2010	$	5.00	$	10.28	$	0.65	$	9.34	$	4.85

(1)Other International primarily consists of EOG's United Kingdom, China and Argentina operations.

Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves Table

The following table sets forth the standardized measure of discounted future net cash flows from projected production of EOG's oil and gas reserves for the years ended December 31, 2012, 2011 and 2010:

			United						Other
			States		Canada		Trinidad		International (1)		Total
2012
	Future cash inflows (2)	$	89,324,274	$	1,816,369	$	2,408,116	$	1,063,854	$	94,612,613
	Future production costs		(35,892,997)		(751,113)		(342,113)		(198,609)		(37,184,832)
	Future development costs		(15,825,040)		(813,061)		(171,737)		(221,893)		(17,031,731)
	Future income taxes		(10,247,007)		-		(691,109)		(212,626)		(11,150,742)
	Future net cash flows		27,359,230		252,195		1,203,157		430,726		29,245,308
	Discount to present value at 10% annual rate		(12,177,896)		146,954		(242,087)		(56,807)		(12,329,836)
	Standardized measure of discounted future net cash flows relating to proved oil and gas reserves	$	15,181,334	$	399,149	$	961,070	$	373,919	$	16,915,472
2011
	Future cash inflows (3)	$	84,518,638	$	5,056,501	$	2,851,545	$	103,853	$	92,530,537
	Future production costs		(33,294,343)		(2,315,110)		(388,199)		(62,938)		(36,060,590)
	Future development costs		(13,811,449)		(1,566,917)		(149,884)		(331)		(15,528,581)
	Future income taxes		(10,539,182)		(81,590)		(794,856)		(2,457)		(11,418,085)
	Future net cash flows		26,873,664		1,092,884		1,518,606		38,127		29,523,281
	Discount to present value at 10% annual rate		(12,498,010)		(456,537)		(334,399)		(9,054)		(13,298,000)
	Standardized measure of discounted future net cash flows relating to proved oil and gas reserves	$	14,375,654	$	636,347	$	1,184,207	$	29,073	$	16,225,281
2010
	Future cash inflows (4)	$	62,063,123	$	6,040,422	$	2,760,819	$	91,805	$	70,956,169
	Future production costs		(22,616,039)		(2,711,415)		(384,147)		(48,953)		(25,760,554)
	Future development costs		(9,596,005)		(1,716,734)		(198,072)		(334)		(11,511,145)
	Future income taxes		(8,503,301)		(129,816)		(850,699)		(3,598)		(9,487,414)
	Future net cash flows		21,347,778		1,482,457		1,327,901		38,920		24,197,056
	Discount to present value at 10% annual rate		(10,718,854)		(736,222)		(339,035)		(11,121)		(11,805,232)
	Standardized measure of discounted future net cash flows relating to proved oil and gas reserves	$	10,628,924	$	746,235	$	988,866	$	27,799	$	12,391,824

(1) Other International includes EOG's United Kingdom, China and Argentina operations.

(2) Estimated crude oil prices used to calculate 2012 future cash inflows for the United States, Canada, Trinidad and Other International were $99.78, $84.77, $94.46 and $109.94, respectively. Estimated NGLs prices used to calculate 2012 future cash inflows for the United States and Canada were $36.95 and $47.80, respectively.  Estimated natural gas prices used to calculate 2012 future cash inflows for the United States, Canada, Trinidad and Other International were $2.63, $2.22, $3.61 and $5.04, respectively.

(3) Estimated crude oil prices used to calculate 2011 future cash inflows for the United States, Canada, Trinidad and Other International were $97.75, $90.70, $92.50 and $102.86, respectively. Estimated NGLs prices used to calculate 2011 future cash inflows for the United States and Canada were $51.77  and $46.97, respectively.  Estimated natural gas prices used to calculate 2011 future cash inflows for the United States, Canada, Trinidad and Other International were $4.03, $3.28, $3.37, and $5.07, respectively.

(4) Estimated crude oil prices used to calculate 2010 future cash inflows for the United States, Canada, Trinidad and Other International were $76.38, $72.59, $69.56 and $73.88, respectively. Estimated NGLs prices used to calculate 2010 future cash inflows for the United States and Canada were $43.85 and $26.56, respectively.  Estimated natural gas prices used to calculate 2010 future cash inflows for the United States, Canada, Trinidad and Other International were $4.36, $3.67, $2.94 and $5.02, respectively.

Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves

Changes in Standardized Measure of Discounted Future Net Cash Flows.  The following table sets forth the changes in the standardized measure of discounted future net cash flows at December 31, for each of the three years in the period ended December 31, 2012:

			United						Other
			States		Canada		Trinidad		International		Total
December 31, 2009		$	5,822,916	$	1,037,244	$	665,563	$	15,295	$	7,541,018
	Sales and transfers of oil and gas produced, net of     production costs		(2,792,005)		(292,857)		(395,379)		(17,720)		(3,497,961)
	Net changes in prices and production costs		2,468,907		(559)		721,796		7,259		3,197,403
	Extensions, discoveries, additions and improved     recovery, net of related costs		4,319,659		75,162		183,453		-		4,578,274
	Development costs incurred		864,700		175,100		67,300		-		1,107,100
	Revisions of estimated development cost		(257,360)		260,290		(767)		9		2,172
	Revisions of previous quantity estimates		(164,748)		(38,382)		(175,002)		4,006		(374,126)
	Accretion of discount		755,001		102,022		101,549		1,778		960,350
	Net change in income taxes		(1,171,384)		101,966		(258,354)		2,469		(1,325,303)
	Purchases of reserves in place		265		-		-		-		265
	Sales of reserves in place		(54,057)		(290,592)		-		-		(344,649)
	Changes in timing and other		837,030		(383,159)		78,707		14,703		547,281
December 31, 2010			10,628,924		746,235		988,866		27,799		12,391,824
	Sales and transfers of oil and gas produced, net of     production costs		(4,296,926)		(278,910)		(504,205)		(15,614)		(5,095,655)
	Net changes in prices and production costs		716,682		(57,545)		331,196		3,328		993,661
	Extensions, discoveries, additions and improved     recovery, net of related costs		6,223,552		22,591		102,548		-		6,348,691
	Development costs incurred		1,422,500		48,200		74,800		-		1,545,500
	Revisions of estimated development cost		(210,919)		64,001		(14,074)		2		(160,990)
	Revisions of previous quantity estimates		(482,496)		(70,718)		(56,884)		801		(609,297)
	Accretion of discount		1,352,740		62,725		159,715		2,782		1,577,962
	Net change in income taxes		(1,049,641)		(118,988)		9,511		13		(1,159,105)
	Purchases of reserves in place		5,241		-		-		-		5,241
	Sales of reserves in place		(658,468)		-		-		-		(658,468)
	Changes in timing and other		724,465		218,756		92,734		9,962		1,045,917
December 31, 2011			14,375,654		636,347		1,184,207		29,073		16,225,281
	Sales and transfers of oil and gas produced, net of    production costs		(5,192,392)		(159,577)		(526,134)		(10,214)		(5,888,317)
	Net changes in prices and production costs		(393,585)		(67,964)		162,600		(2,283)		(301,232)
	Extensions, discoveries, additions and improved     recovery, net of related costs		5,517,945		79,529		-		484,648		6,082,122
	Development costs incurred		2,042,300		23,600		23,500		5,200		2,094,600
	Revisions of estimated development cost		1,987,330		383,215		(28,835)		(234)		2,341,476
	Revisions of previous quantity estimates		(3,286,943)		(396,408)		(62,285)		2,809		(3,742,827)
	Accretion of discount		1,832,377		63,635		178,298		2,907		2,077,217
	Net change in income taxes		174,418		-		88,853		(138,206)		125,065
	Purchases of reserves in place		64,317		-		-		5,623		69,940
	Sales of reserves in place		(869,534)		(44,227)		-		-		(913,761)
	Changes in timing and other		(1,070,553)		(119,001)		(59,134)		(5,404)		(1,254,092)
December 31, 2012		$	15,181,334	$	399,149	$	961,070	$	373,919	$	16,915,472