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Oil and Gas Exploration and Production Industries Disclosures (Tables)
 12 Months Ended
Dec. 31, 2016
Oil and Gas Exploration and Production Industries Disclosures [Abstract]  
Net Proved and Proved Developed Oil and Gas Reserve Quantities
The following tables set forth EOG's net proved reserves at December 31 for each of the four years in the period ended December 31, 2016, and the changes in the net proved reserves for each of the three years in the period ended December 31, 2016, as estimated by the Engineering and Acquisitions Department of EOG:
NET PROVED RESERVE SUMMARY
 
United
States
 
Trinidad
 
Other
International (1)
 
Total
NET PROVED RESERVES
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Crude Oil (MBbl) (2)
 
 
 
 
 
 
 
Net proved reserves at December 31, 2013
880,049

 
1,590

 
18,901

 
900,540

Revisions of previous estimates
28,301

 
99

 
(378
)
 
28,022

Purchases in place
9,705

 
—

 
—

 
9,705

Extensions, discoveries and other additions
319,540

 
—

 
14

 
319,554

Sales in place
(4,967
)
 
—

 
(7,656
)
 
(12,623
)
Production
(102,946
)
 
(350
)
 
(2,152
)
 
(105,448
)
Net proved reserves at December 31, 2014
1,129,682

 
1,339

 
8,729

 
1,139,750

Revisions of previous estimates
(114,924
)
 
(1
)
 
—

 
(114,925
)
Purchases in place
35,922

 
—

 
—

 
35,922

Extensions, discoveries and other additions
141,310

 
63

 
13

 
141,386

Sales in place
(730
)
 
—

 
(10
)
 
(740
)
Production
(103,400
)
 
(332
)
 
(65
)
 
(103,797
)
Net proved reserves at December 31, 2015
1,087,860

 
1,069

 
8,667

 
1,097,596

Revisions of previous estimates
42,040

 
54

 
861

 
42,955

Purchases in place
25,795

 
—

 
—

 
25,795

Extensions, discoveries and other additions
123,441

 
—

 
—

 
123,441

Sales in place
(8,791
)
 
—

 
—

 
(8,791
)
Production
(101,854
)
 
(284
)
 
(1,273
)
 
(103,411
)
Net proved reserves at December 31, 2016
1,168,491

 
839

 
8,255

 
1,177,585

 
 
 
 
 
 
 
 
Natural Gas Liquids (MBbl) (2)
 

 
 

 
 

 
 

Net proved reserves at December 31, 2013
376,002

 
—

 
1,204

 
377,206

Revisions of previous estimates
27,450

 
—

 
(7
)
 
27,443

Purchases in place
1,812

 
—

 
—

 
1,812

Extensions, discoveries and other additions
91,683

 
—

 
—

 
91,683

Sales in place
(956
)
 
—

 
(823
)
 
(1,779
)
Production
(29,061
)
 
—

 
(236
)
 
(29,297
)
Net proved reserves at December 31, 2014
466,930

 
—

 
138

 
467,068

Revisions of previous estimates
(113,290
)
 
—

 
68

 
(113,222
)
Purchases in place
8,251

 
—

 
—

 
8,251

Extensions, discoveries and other additions
49,147

 
—

 
—

 
49,147

Sales in place
(84
)
 
—

 
(187
)
 
(271
)
Production
(28,079
)
 
—

 
(19
)
 
(28,098
)
Net proved reserves at December 31, 2015
382,875

 
—

 
—

 
382,875

Revisions of previous estimates
53,771

 
—

 
—

 
53,771

Purchases in place
1,284

 
—

 
—

 
1,284

Extensions, discoveries and other additions
41,862

 
—

 
—

 
41,862

Sales in place
(33,548
)
 
—

 
—

 
(33,548
)
Production
(29,878
)
 
—

 
—

 
(29,878
)
Net proved reserves at December 31, 2016
416,366

 
—

 
—

 
416,366

 
United
States
 
Trinidad
 
Other
International (1)
 
Total
Natural Gas (Bcf) (3)
 
 
 
 
 
 
 
Net proved reserves at December 31, 2013
4,398.7

 
520.7

 
125.4

 
5,044.8

Revisions of previous estimates
252.2

 
12.9

 
5.5

 
270.6

Purchases in place
17.1

 
—

 
—

 
17.1

Extensions, discoveries and other additions
638.3

 
4.5

 
4.7

 
647.5

Sales in place
(52.4
)
 
—

 
(78.7
)
 
(131.1
)
Production
(348.4
)
 
(132.5
)
 
(25.4
)
 
(506.3
)
Net proved reserves at December 31, 2014
4,905.5

 
405.6

 
31.5

 
5,342.6

Revisions of previous estimates
(1,453.1
)
 
16.8

 
5.6

 
(1,430.7
)
Purchases in place
72.3

 
—

 
—

 
72.3

Extensions, discoveries and other additions
306.3

 
21.7

 
4.4

 
332.4

Sales in place
(3.9
)
 
—

 
(11.1
)
 
(15.0
)
Production
(337.3
)
 
(127.5
)
 
(10.9
)
 
(475.7
)
Net proved reserves at December 31, 2015
3,489.8

 
316.6

 
19.5

 
3,825.9

Revisions of previous estimates
298.4

 
29.5

 
5.2

 
333.1

Purchases in place
91.5

 
—

 
—

 
91.5

Extensions, discoveries and other additions
202.1

 
59.9

 
—

 
262.0

Sales in place
(752.0
)
 
—

 
—

 
(752.0
)
Production
(308.6
)
 
(125.1
)
 
(8.9
)
 
(442.6
)
Net proved reserves at December 31, 2016
3,021.2

 
280.9

 
15.8

 
3,317.9

 
 
 
 
 
 
 
 
Oil Equivalents (MBoe) (2)
 

 
 

 
 

 
 

Net proved reserves at December 31, 2013
1,989,166

 
88,364

 
41,013

 
2,118,543

Revisions of previous estimates
97,782

 
2,245

 
541

 
100,568

Purchases in place
14,367

 
—

 
—

 
14,367

Extensions, discoveries and other additions
517,613

 
758

 
796

 
519,167

Sales in place
(14,661
)
 
—

 
(21,602
)
 
(36,263
)
Production
(190,065
)
 
(22,430
)
 
(6,631
)
 
(219,126
)
Net proved reserves at December 31, 2014
2,414,202

 
68,937

 
14,117

 
2,497,256

Revisions of previous estimates
(470,401
)
 
2,802

 
995

 
(466,604
)
Purchases in place
56,215

 
—

 
—

 
56,215

Extensions, discoveries and other additions
241,513

 
3,682

 
736

 
245,931

Sales in place
(1,467
)
 
—

 
(2,039
)
 
(3,506
)
Production
(187,701
)
 
(21,578
)
 
(1,896
)
 
(211,175
)
Net proved reserves at December 31, 2015
2,052,361

 
53,843

 
11,913

 
2,118,117

Revisions of previous estimates
145,542

 
4,978

 
1,722

 
152,242

Purchases in place
42,330

 
—

 
—

 
42,330

Extensions, discoveries and other additions
198,973

 
9,990

 
—

 
208,963

Sales in place
(167,669
)
 
—

 
—

 
(167,669
)
Production
(183,145
)
 
(21,150
)
 
(2,755
)
 
(207,050
)
Net proved reserves at December 31, 2016
2,088,392

 
47,661

 
10,880

 
2,146,933

 
(1)
Other International includes EOG's United Kingdom, China, Canada and Argentina operations. The Argentina operations were sold in the third quarter of 2016.
(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 a 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
 
United
States
 
Trinidad
 
Other
International (1)
 
Total
NET PROVED DEVELOPED RESERVES
 
 
 
 
 
 
 
Crude Oil (MBbl)
 
 
 
 
 
 
 
December 31, 2013
382,517

 
1,505

 
7,034

 
391,056

December 31, 2014
493,694

 
1,339

 
115

 
495,148

December 31, 2015
444,070

 
1,069

 
63

 
445,202

December 31, 2016
507,531

 
839

 
8,255

 
516,625

Natural Gas Liquids (MBbl)
 

 
 

 
 

 
 

December 31, 2013
199,964

 
—

 
896

 
200,860

December 31, 2014
264,611

 
—

 
138

 
264,749

December 31, 2015
205,898

 
—

 
—

 
205,898

December 31, 2016
230,219

 
—

 
—

 
230,219

Natural Gas (Bcf)
 

 
 

 
 

 
 

December 31, 2013
2,597.3

 
494.6

 
121.5

 
3,213.4

December 31, 2014
3,102.8

 
396.9

 
28.6

 
3,528.3

December 31, 2015
2,211.2

 
297.6

 
19.5

 
2,528.3

December 31, 2016
1,804.4

 
262.2

 
15.8

 
2,082.4

Oil Equivalents (MBoe)
 

 
 

 
 

 
 

December 31, 2013
1,015,359

 
83,933

 
28,184

 
1,127,476

December 31, 2014
1,275,447

 
67,484

 
5,016

 
1,347,947

December 31, 2015
1,018,491

 
50,677

 
3,309

 
1,072,477

December 31, 2016
1,038,483

 
44,543

 
10,880

 
1,093,906

NET PROVED UNDEVELOPED RESERVES
 

 
 

 
 

 
 

Crude Oil (MBbl)
 

 
 

 
 

 
 

December 31, 2013
497,532

 
85

 
11,867

 
509,484

December 31, 2014
635,988

 
—

 
8,614

 
644,602

December 31, 2015
643,790

 
—

 
8,604

 
652,394

December 31, 2016
660,960

 
—

 
—

 
660,960

Natural Gas Liquids (MBbl)
 

 
 

 
 

 
 

December 31, 2013
176,038

 
—

 
308

 
176,346

December 31, 2014
202,319

 
—

 
—

 
202,319

December 31, 2015
176,977

 
—

 
—

 
176,977

December 31, 2016
186,147

 
—

 
—

 
186,147

Natural Gas (Bcf)
 

 
 

 
 

 
 

December 31, 2013
1,801.4

 
26.1

 
3.9

 
1,831.4

December 31, 2014
1,802.7

 
8.7

 
2.9

 
1,814.3

December 31, 2015
1,278.6

 
19.0

 
—

 
1,297.6

December 31, 2016
1,216.8

 
18.7

 
—

 
1,235.5

Oil Equivalents (MBoe)
 

 
 

 
 

 
 

December 31, 2013
973,807

 
4,431

 
12,829

 
991,067

December 31, 2014
1,138,755

 
1,453

 
9,101

 
1,149,309

December 31, 2015
1,033,870

 
3,166

 
8,604

 
1,045,640

December 31, 2016
1,049,909

 
3,118

 
—

 
1,053,027

 
(1)
Other International includes EOG's United Kingdom, China, Canada and Argentina operations. The Argentina operations were sold in the third quarter of 2016.
Net Proved Undeveloped Reserves
The following table presents the changes in EOG's total proved undeveloped reserves during 2016, 2015 and 2014 (in MBoe):
 
2016
 
2015
 
2014
 
 
 
 
 
 
Balance at January 1
1,045,640

 
1,149,309

 
991,067

Extensions and Discoveries
138,101

 
205,152

 
403,713

Revisions
64,413

 
(241,973
)
 
(79,630
)
Acquisition of Reserves
—

 
54,458

 
4,239

Sale of Reserves
(45,917
)
 
—

 
(10,176
)
Conversion to Proved Developed Reserves
(149,210
)
 
(121,306
)
 
(159,904
)
Balance at December 31
1,053,027

 
1,045,640

 
1,149,309
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, 2016 and 2015:
 
2016
 
2015
 
 
 
 
Proved properties
$
45,751,965

 
$
49,623,518

Unproved properties
3,840,126

 
989,723

Total
49,592,091

 
50,613,241

Accumulated depreciation, depletion and amortization
(26,247,062
)
 
(28,877,593
)
Net capitalized costs
$
23,345,029

 
$
21,735,648
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, 2016, 2015 and 2014:
 
United
States
 
Trinidad
 
Other
International (1)
 
Total
2016
 
 
 
 
 
 
 
Acquisition Costs of Properties
 
 
 
 
 
 
 
Unproved (2)
$
3,216,598

 
$
—

 
$
36

 
$
3,216,634

Proved (3)
749,023

 
—

 
—

 
749,023

Subtotal
3,965,621

 
—

 
36

 
3,965,657

Exploration Costs
156,295

 
2,695

 
6,761

 
165,751

Development Costs (4)
2,252,713

 
72,147

 
(10,984
)
 
2,313,876

Total
$
6,374,629

 
$
74,842

 
$
(4,187
)
 
$
6,445,284

2015
 

 
 

 
 

 
 

Acquisition Costs of Properties
 

 
 

 
 

 
 

Unproved
$
133,801

 
$
—

 
$
56

 
$
133,857

Proved
480,617

 
—

 
—

 
480,617

Subtotal
614,418

 
—

 
56

 
614,474

Exploration Costs
206,814

 
22,837

 
23,041

 
252,692

Development Costs (5)
3,847,813

 
102,715

 
110,589

 
4,061,117

Total
$
4,669,045

 
$
125,552

 
$
133,686

 
$
4,928,283

2014
 

 
 

 
 

 
 

Acquisition Costs of Properties
 

 
 

 
 

 
 

Unproved
$
365,915

 
$
—

 
$
4,499

 
$
370,414

Proved
138,772

 
—

 
329

 
139,101

Subtotal
504,687

 
—

 
4,828

 
509,515

Exploration Costs
332,703

 
2,794

 
60,476

 
395,973

Development Costs (6)
6,638,192

 
89,555

 
271,534

 
6,999,281

Total
$
7,475,582

 
$
92,349

 
$
336,838

 
$
7,904,769

 
(1)
Other International primarily consists of EOG's United Kingdom, China, Canada and Argentina operations. The Argentina operations were sold in the third quarter of 2016.
(2)
Includes non-cash unproved leasehold acquisition costs of $3,102 million related to the Yates transaction.
(3)
Includes non-cash proved property acquisition costs of $732 million related to the Yates transaction.
(4)
Includes Asset Retirement Costs of $25 million, $(3) million and $(42) million for the United States, Trinidad and Other International, respectively.  Excludes other property, plant and equipment.
(5)
Includes Asset Retirement Costs of $32 million, $15 million and $6 million for the United States, Trinidad and Other International, respectively.  Excludes other property, plant and equipment.
(6)
Includes Asset Retirement Costs of $149 million, $14 million and $33 million for the United States, 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, 2016, 2015 and 2014:
 
United
States
 
Trinidad
 
Other
International (2)
 
Total
2016
 
 
 
 
 
 
 
Crude Oil and Condensate, Natural Gas Liquids and Natural Gas Revenues
$
5,177,989

 
$
243,708

 
$
75,046

 
$
5,496,743

Other
81,386

 
(8
)
 
25

 
81,403

Total
5,259,375

 
243,700

 
75,071

 
5,578,146

Exploration Costs
115,990

 
2,647

 
6,316

 
124,953

Dry Hole Costs
10,529

 
—

 
128

 
10,657

Transportation Costs
753,791

 
1,181

 
9,134

 
764,106

Production Costs
1,163,827

 
27,113

 
63,073

 
1,254,013

Impairments
611,297

 
7,773

 
1,197

 
620,267

Depreciation, Depletion and Amortization
3,249,792

 
145,440

 
42,052

 
3,437,284

Income (Loss) Before Income Taxes
(645,851
)
 
59,546

 
(46,829
)
 
(633,134
)
Income Tax Provision (Benefit)
(230,377
)
 
5,526

 
(1,562
)
 
(226,413
)
Results of Operations
$
(415,474
)
 
$
54,020

 
$
(45,267
)
 
$
(406,721
)
2015
 

 
 

 
 

 
 

Crude Oil and Condensate, Natural Gas Liquids and Natural Gas Revenues
$
5,962,753

 
$
381,761

 
$
58,744

 
$
6,403,258

Other
47,464

 
(3
)
 
448

 
47,909

Total
6,010,217

 
381,758

 
59,192

 
6,451,167

Exploration Costs
139,753

 
2,071

 
7,670

 
149,494

Dry Hole Costs
956

 
5,635

 
8,155

 
14,746

Transportation Costs
838,428

 
1,290

 
9,601

 
849,319

Production Costs
1,486,189

 
28,862

 
66,080

 
1,581,131

Impairments
6,402,908

 
—

 
210,638

 
6,613,546

Depreciation, Depletion and Amortization
3,017,386

 
154,588

 
18,469

 
3,190,443

Income (Loss) Before Income Taxes
(5,875,403
)
 
189,312

 
(261,421
)
 
(5,947,512
)
Income Tax Provision (Benefit)
(2,128,183
)
 
43,739

 
(2,111
)
 
(2,086,555
)
Results of Operations
$
(3,747,220
)
 
$
145,573

 
$
(259,310
)
 
$
(3,860,957
)
2014
 

 
 

 
 

 
 

Crude Oil and Condensate, Natural Gas Liquids and Natural Gas Revenues
$
11,771,777

 
$
512,675

 
$
308,465

 
$
12,592,917

Other
49,950

 
37

 
4,257

 
54,244

Total
11,821,727

 
512,712

 
312,722

 
12,647,161

Exploration Costs
162,434

 
2,185

 
19,769

 
184,388

Dry Hole Costs
25,408

 
—

 
23,082

 
48,490

Transportation Costs
957,522

 
617

 
14,037

 
972,176

Production Costs
1,940,074

 
38,301

 
171,652

 
2,150,027

Impairments
331,792

 
—

 
411,783

 
743,575

Depreciation, Depletion and Amortization
3,571,313

 
188,250

 
122,157

 
3,881,720

Income (Loss) Before Income Taxes
4,833,184

 
283,359

 
(449,758
)
 
4,666,785

Income Tax Provision
1,722,914

 
74,588

 
23,602

 
1,821,104

Results of Operations
$
3,110,270

 
$
208,771

 
$
(473,360
)
 
$
2,845,681

 
(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, 2016.
(2)
Other International primarily consists of EOG's United Kingdom, China, Canada and Argentina operations. The Argentina operations were sold in the third quarter of 2016.
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, 2016, 2015 and 2014:
 
United
States
 
Trinidad
 
Other
International (1)
 
Composite
 
 
 
 
 
 
 
 
Year Ended December 31, 2016
$
4.58

 
$
1.23

 
$
22.43

 
$
4.48

Year Ended December 31, 2015
$
5.81

 
$
1.29

 
$
33.78

 
$
5.85

Year Ended December 31, 2014
$
6.44

 
$
1.34

 
$
24.60

 
$
6.46

 
(1)
Other International primarily consists of EOG's United Kingdom, China, Canada and Argentina operations. The Argentina operations were sold in the third quarter of 2016.
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, 2016, 2015 and 2014:
 
United
States
 
Trinidad
 
Other
International (1)
 
Total
2016
 
 
 
 
 
 
 
Future cash inflows (2)
$
57,913,314

 
$
524,523

 
$
402,587

 
$
58,840,424

Future production costs
(27,625,833
)
 
(165,757
)
 
(227,293
)
 
(28,018,883
)
Future development costs
(12,602,699
)
 
(103,631
)
 
(35,602
)
 
(12,741,932
)
Future income taxes
(3,151,319
)
 
(60,001
)
 
—

 
(3,211,320
)
Future net cash flows
14,533,463

 
195,134

 
139,692

 
14,868,289

Discount to present value at 10% annual rate
(6,039,736
)
 
(9,384
)
 
(7,012
)
 
(6,056,132
)
Standardized measure of discounted future net cash flows relating to proved oil and gas reserves
$
8,493,727

 
$
185,750

 
$
132,680

 
$
8,812,157

2015
 

 
 

 
 

 
 

Future cash inflows (3)
$
67,242,928

 
$
954,779

 
$
522,941

 
$
68,720,648

Future production costs
(31,707,743
)
 
(183,607
)
 
(169,505
)
 
(32,060,855
)
Future development costs
(15,579,923
)
 
(140,541
)
 
(65,347
)
 
(15,785,811
)
Future income taxes
(4,400,542
)
 
(215,659
)
 
—

 
(4,616,201
)
Future net cash flows
15,554,720

 
414,972

 
288,089

 
16,257,781

Discount to present value at 10% annual rate
(6,589,253
)
 
(33,848
)
 
(13,284
)
 
(6,636,385
)
Standardized measure of discounted future net cash flows relating to proved oil and gas reserves
$
8,965,467

 
$
381,124

 
$
274,805

 
$
9,621,396

2014
 

 
 

 
 

 
 

Future cash inflows (4)
$
144,355,692

 
$
1,615,280

 
$
979,249

 
$
146,950,221

Future production costs
(51,112,604
)
 
(277,844
)
 
(242,845
)
 
(51,633,293
)
Future development costs
(20,270,439
)
 
(84,576
)
 
(139,750
)
 
(20,494,765
)
Future income taxes
(22,725,618
)
 
(460,096
)
 
—

 
(23,185,714
)
Future net cash flows
50,247,031

 
792,764

 
596,654

 
51,636,449

Discount to present value at 10% annual rate
(23,542,990
)
 
(110,228
)
 
(59,813
)
 
(23,713,031
)
Standardized measure of discounted future net cash flows relating to proved oil and gas reserves
$
26,704,041

 
$
682,536

 
$
536,841

 
$
27,923,418

 
(1)
Other International includes EOG's United Kingdom, China, Canada and Argentina operations. The Argentina operations were sold in the third quarter of 2016.
(2)
Estimated crude oil prices used to calculate 2016 future cash inflows for the United States, Trinidad and Other International were $40.70, $34.79 and $39.55, respectively. Estimated NGL price used to calculate 2016 future cash inflows for the United States was $14.69. Estimated natural gas prices used to calculate 2016 future cash inflows for the United States, Trinidad and Other International were $1.40, $1.76 and $4.84, respectively.
(3)
Estimated crude oil prices used to calculate 2015 future cash inflows for the United States, Trinidad and Other International were $49.58, $38.83 and $47.76, respectively. Estimated NGL price used to calculate 2015 future cash inflows for the United States was $15.17. Estimated natural gas prices used to calculate 2015 future cash inflows for the United States, Trinidad and Other International were $2.15, $2.88 and $5.60, respectively.
(4)
Estimated crude oil prices used to calculate 2014 future cash inflows for the United States, Trinidad and Other International were $97.51, $80.60 and $94.09, respectively. Estimated NGL prices used to calculate 2014 future cash inflows for the United States and Other International were $34.29 and $27.03, respectively. Estimated natural gas prices used to calculate 2014 future cash inflows for the United States, Trinidad and Other International were $3.71, $3.71 and $5.14, respectively.
Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves
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, 2016:
 
United
States
 
Trinidad
 
Other
International (1)
 
Total
 
 
 
 
 
 
 
 
December 31, 2013
$
19,576,901

 
$
876,640

 
$
879,891

 
$
21,333,432

Sales and transfers of oil and gas produced, net of production costs
(8,874,180
)
 
(473,757
)
 
(122,777
)
 
(9,470,714
)
Net changes in prices and production costs
1,481,668

 
(12,079
)
 
(206,412
)
 
1,263,177

Extensions, discoveries, additions and improved recovery, net of related costs
8,074,550

 
3,113

 
6,189

 
8,083,852

Development costs incurred
2,818,800

 
12,800

 
3,500

 
2,835,100

Revisions of estimated development cost
1,696,916

 
9,981

 
95,838

 
1,802,735

Revisions of previous quantity estimates
1,741,918

 
35,001

 
35,613

 
1,812,532

Accretion of discount
2,612,286

 
133,019

 
88,045

 
2,833,350

Net change in income taxes
(3,743,300
)
 
91,438

 
562

 
(3,651,300
)
Purchases of reserves in place
317,785

 
—

 
—

 
317,785

Sales of reserves in place
(189,808
)
 
—

 
(289,071
)
 
(478,879
)
Changes in timing and other
1,190,505

 
6,380

 
45,463

 
1,242,348

December 31, 2014
26,704,041

 
682,536

 
536,841

 
27,923,418

Sales and transfers of oil and gas produced, net of production costs
(3,685,600
)
 
(351,606
)
 
16,489

 
(4,020,717
)
Net changes in prices and production costs
(29,993,699
)
 
(370,503
)
 
(305,148
)
 
(30,669,350
)
Extensions, discoveries, additions and improved recovery, net of related costs
1,028,410

 
47,613

 
19,875

 
1,095,898

Development costs incurred
2,135,800

 
500

 
1,400

 
2,137,700

Revisions of estimated development cost
4,087,093

 
(34,647
)
 
26,935

 
4,079,381

Revisions of previous quantity estimates
(4,084,572
)
 
33,285

 
(587
)
 
(4,051,874
)
Accretion of discount
3,699,330

 
104,464

 
53,685

 
3,857,479

Net change in income taxes
9,550,847

 
177,576

 
—

 
9,728,423

Purchases of reserves in place
123,542

 
—

 
—

 
123,542

Sales of reserves in place
(23,424
)
 
—

 
(13,664
)
 
(37,088
)
Changes in timing and other
(576,301
)
 
91,906

 
(61,021
)
 
(545,416
)
December 31, 2015
8,965,467

 
381,124

 
274,805

 
9,621,396

Sales and transfers of oil and gas produced, net of production costs
(3,260,372
)
 
(215,414
)
 
(2,839
)
 
(3,478,625
)
Net changes in prices and production costs
(3,352,802
)
 
(182,876
)
 
(143,924
)
 
(3,679,602
)
Extensions, discoveries, additions and improved recovery, net of related costs
865,066

 
42,201

 
—

 
907,267

Development costs incurred
1,207,000

 
3,900

 
19,100

 
1,230,000

Revisions of estimated development cost
2,092,769

 
22,596

 
6,343

 
2,121,708

Revisions of previous quantity estimates
1,013,753

 
36,648

 
2,619

 
1,053,020

Accretion of discount
970,388

 
56,566

 
27,481

 
1,054,435

Net change in income taxes
738,416

 
129,622

 
—

 
868,038

Purchases of reserves in place
377,872

 
—

 
—

 
377,872

Sales of reserves in place
(375,793
)
 
—

 
—

 
(375,793
)
Changes in timing and other
(748,037
)
 
(88,617
)
 
(50,905
)
 
(887,559
)
December 31, 2016
$
8,493,727

 
$
185,750

 
$
132,680

 
$
8,812,157

 
(1)
Other International includes EOG's United Kingdom, China, Canada and Argentina operations. The Argentina operations were sold in the third quarter of 2016.