Chapter 2

Tabular Data and Graphical Images in 

Support of the U.S. Geological Survey 

National Oil and Gas Assessment—

Bighorn Basin Province (5034)

By T.R. Klett and P.A. Le

Chapter 2 of 

Petroleum Systems and Geologic Assessment of Oil and Gas in 

the Bighorn Basin Province, Wyoming and Montana

By U.S. Geological Survey Bighorn Basin Province Assessment Team

U.S. Geological Survey Digital Data Series DDS–69–V

U.S. Department of the Interior

U.S. Geological Survey

Click here to return to

Volume Title Page
U.S. Department of the Interior

KEN SALAZAR, Secretary

U.S. Geological Survey

Marcia K. McNutt, Director

U.S. Geological Survey, Reston, Virginia: 2010

For more information on the USGS—the Federal source for science about the Earth, its natural and living resources, 

natural hazards, and the environment, visit http://www.usgs.gov or call 1-888-ASK-USGS

For an overview of USGS information products, including maps, imagery, and publications, 

visit http://www.usgs.gov/pubprod

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Any use of trade, product, or firm names is for descriptive purposes only and does not imply endorsement by the 

U.S. Government.

Although this report is in the public domain, permission must be secured from the individual copyright owners to 

reproduce any copyrighted materials contained within this report.

Suggested citation:

Klett, T.R., and Le, P.A., 2010, Tabular data and graphical images in support of the U.S. Geological Survey national oil 

and gas assessment—Bighorn Basin Province (5034): U.S. Geological Survey Digital Data Series DDS–69–V, 20 p.

ISBN: 1-4113-2667-5
iii

Contents

Introduction.....................................................................................................................................................1

Disclaimers .....................................................................................................................................................1

Data Sources..................................................................................................................................................1

Data Overview................................................................................................................................................1

Data Tables ............................................................................................................................................1

Summary Tables....................................................................................................................................2

Graphs.....................................................................................................................................................2

Numeric Codes...............................................................................................................................................2

Summary Tables.............................................................................................................................................2

Graphical Data................................................................................................................................................2

File List.............................................................................................................................................................4

Tabular Data....................................................................................................................................................4

References Cited..........................................................................................................................................20

Note: Individual .pdf file names are listed on page 4 and are linked to the respective .pdf files
Introduction

This chapter describes data used in support of the process 

being applied by the U.S. Geological Survey (USGS) National 

Oil and Gas Assessment (NOGA) project. Digital tabular data 

used in this report and archival data that permit the user to 

perform further analyses are available elsewhere on this CD–

ROM. Computers and software may import the data without 

transcription from the Portable Document Format files (.pdf 

files) of the text by the reader. Because of the number and 

variety of platforms and software available, graphical images 

are provided as .pdf files and tabular data are provided in a 

raw form as tab-delimited text files (.tab files).

Disclaimers

This publication was prepared by an agency of the United 

States Government. Any use of trade, product, or firm names 

is for descriptive purposes only and does not imply endorsement by the United States Government.

This database, DDS 69-V, has been approved for release 

and publication by the Director of the USGS. Although this 

database has been subjected to rigorous review and is substantially complete, the USGS reserves the right to revise the 

data pursuant to further analysis and review. Furthermore, it 

is released on condition that neither the USGS nor the United 

States Government may be held liable for any damages resulting from its authorized or unauthorized use.

Data Sources

Crude oil and natural gas production data (including all 

volumetric and descriptive data such as cumulative production, remaining reserves, known recoverable volumes, major 

producing reservoirs, and petroleum type) and historical data 

(including field-discovery dates, well-completion dates, exploration objectives, and well depths) for fields, reservoirs, and 

wells are derived from commercial databases leased and (or) 

Tabular Data and Graphical Images in Support of the 

U.S. Geological Survey National Oil and Gas 

Assessment—Bighorn Basin Province (5034)

By T.R. Klett and P.A. Le

purchased by the USGS, including (1) PI/Dwights Plus US 

Production Data (IHS Energy Group, 2007a), (2) PI/Dwights 

Plus US Well Data (IHS Energy Group, 2007b), and (3) NRG 

Associates, Inc., “Significant Oil and Gas Fields of the United 

States” (NRG Associates, 2007), as well as older versions of 

these databases. Data from these databases are subject to proprietary constraints, but derivative representations in the form 

of graphs and summary statistics are allowed to be published 

and were prepared for each assessment unit. To supplement 

commercial databases, additional data are obtained, where 

available, from operators, other Federal and State agencies, or 

published geological reports.

The PI/Dwights Plus US Production database provides 

production data for wells, leases, or production units. The PI/

Dwights Plus US Well database provides individual well data 

(including data for dry holes), including well identifications, 

locations, initial and final well status classifications, completion dates, and information on penetrated formations. The 

NRG Associates, Inc., “Significant Oil and Gas Fields of the 

United States” database provides volumetric and production 

data for fields and reservoirs.

Data Overview

This report provides various data files supporting the 

NOGA project. The files contain data that are the source for 

the various graphs, data tables, and summary tables used in the 

assessment process. Tabular data are provided as tab-delimited 

text files (.tab files) usable in spreadsheet and database software. Graphical and summary data are provided as Portable 

Document Format files (.pdf files). File name conventions are 

as follows:

Data Tables

eco####.tab

fed####.tab

own####.tab
2 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

sta####.tab

vol####.tab

inf####.tab

ins####.tab

kvol####.tab

Summary Tables

c######.pdf

d######.pdf

u######.pdf

Graphs

em######.pdf

fp######.pdf

g######.pdf

k######.pdf

For identification purposes, numbers in the positions 

occupied by the four symbols “####” represent the province 

code. Files with these numbers contain data for the entire 

province. Files having numbers in the positions occupied by 

the six symbols “######” (which represent the last six digits 

of the assessment-unit code) contain data only for that assessment unit.

Numeric Codes

A hierarchical numeric code identifies each region, 

province, total petroleum system, and assessment unit. The 

criteria for assigning codes are uniform throughout the NOGA 

project and throughout all resulting publications. The numeric 

codes used in this study are listed below.

Unit Name Code

Region North America 5

Province Bighorn Basin 5034

Total Petroleum 

System

Phosphoria 503401

Cretaceous-Tertiary Composite 503402

Assessment 

Units

Paleozoic-Mesozoic Conventional 

Oil and Gas

50340101

Cretaceous-Tertiary Conventional 

Oil and Gas

50340201

Muddy-Frontier Sandstone and 

Mowry Fractured Shale Continuous Gas

50340261

Mowry Fractured Shale Continuous Oil50340262

Cody Sandstone Continuous Gas 50340263

Mesaverde Sandstone Continuous 

Gas

50340264

Mesaverde-Meeteetse Formation 

Coalbed Gas

50340281

Fort Union Formation Coalbed 

Gas

50340282

The assessment-unit portion of the code (last two digits) 

defines the type of assessment unit. Numbers from 01 to 59 

represent conventional assessment units, 61 to 79 represent 

continuous oil or gas assessment units, and 81 to 99 represent 

coalbed-gas assessment units. No total petroleum system 

or assessment-unit codes end with 0, for example 503400, 

50340160 or 50340180.

To maintain the conventional labeling of files 

(8-character name and 3-character extension), some file names 

that contain assessment-unit numbers do not include the first 

two digits. For example, a summary table that contains input 

data for the Paleozoic-Mesozoic Conventional Oil and Gas 

assessment unit is labeled “c340101.pdf.”

Summary Tables

The c######.pdf and u######.pdf files are copies of the 

completed input data forms used in the assessment process. 

The c######.pdf files contain the Seventh Approximation 

Data Forms for Conventional Assessment Units. The 

u######.pdf files contain the FORSPAN Assessment Model 

for Continuous Accumulations–Basic Input Data Form. These 

data are defined in the inf####.tab and ins####.tab sections of 

this report.

The d######.pdf files contain three tables of known 

and grown petroleum volumes in an assessment unit as a 

whole and in terms of discovery history. Grown field sizes 

are defined as known accumulation sizes that were adjusted 

upward to account for estimated future reserve growth. NA 

means not applicable and is shown in place of volumes for 

which only one field is present to protect the proprietary nature 

of the data.

Graphical Data

The fp######.pdf files contain graphs of input data 

and estimated petroleum resource volumes for continuous 

assessment units. The data are defined in the inf####.tab and 

vol####.tab sections of this report. The graphs contained 

in these files are derived from a report generated by a commercial software package. The quality of these preformatted 

graphs, therefore, does not necessarily meet USGS editorial 

standards.

The em######.pdf files contain graphs of input data 

and estimated petroleum resource volumes for conventional 

assessment units. The data are defined in the ins####.tab and 

vol####.tab sections of this report. The graphs contained 

in these files are derived from a report generated by a commercial software package. The quality of these preformatted 
Graphical Data 3

graphs, therefore, does not necessarily meet USGS editorial 

standards.

The g######.pdf and k######.pdf files contain graphs 

of exploration and discovery data for conventional assessment 

units. The volumetric data are defined in the kvol####.tab 

sections of this report. To protect the proprietary nature of the 

data, these files are not provided if the total number of accumulations in the assessment unit that are greater than or equal 

to the specified minimum size is less than four.

Two sets of exploration-activity and discovery-history 

graphs are provided for each of the assessment units, one 

set showing known field sizes (cumulative production plus 

remaining reserves) and the other showing field sizes that were 

adjusted to compensate for potential reserve growth that may 

occur in the next 30 years (labeled “grown”). Within each set 

of graphs, oil fields and gas fields are treated separately. The 

graphs include:

• Cumulative Number of New-Field Wildcat Wells vs. 

Drilling-Completion Year

• Number of New-Field Wildcat Wells vs. DrillingCompletion Year

• Oil- or Gas-Accumulation Size (MMBO or BCFG) vs. 

Oil- or Gas-Accumulation Rank by Size (With Respect 

to Discovery Halves or Thirds)

• Number of Oil or Gas Accumulations vs. Oil- or GasAccumulation Size Classes (MMBO or BCFG) (With 

Respect to Discovery Halves or Thirds)

• Volume of Oil or Gas (MMBO or BCFG) vs. Oil- or 

Gas-Accumulation Size Classes (MMBO or BCFG)

• Oil- or Gas-Accumulation Size (MMBO or BCFG) vs. 

Accumulation-Discovery Year

• Oil- or Gas-Accumulation Size (MMBO or BCFG) vs. 

Cumulative Number of New-Field Wildcat Wells

• Cumulative Oil or Gas Volume (MMBO or BCFG) vs. 

Accumulation-Discovery Year

• Cumulative Oil or Gas Volume (MMBO or BCFG) vs. 

Cumulative Number of New-Field Wildcat Wells

• Cumulative Number of Oil or Gas Accumulations vs. 

Accumulation-Discovery Year

• Cumulative Number of Oil or Gas Accumulations vs. 

Cumulative Number of New-Field Wildcat Wells

• Reservoir Depth, Oil or Gas Accumulations (ft) vs. 

Accumulation-Discovery Year

• Reservoir Depth, Oil or Gas Accumulations (ft) vs. 

Cumulative Number of New-Field Wildcat Wells

• Gas/Oil, Oil Accumulations (CFG/BO) vs. Mean Reservoir Depth (ft)

• NGL/Gas, Oil Accumulations (BNGL/MMCFG) vs. 

Mean Reservoir Depth (ft)

• Liquids/Gas, Gas Accumulations (BL/MMCFG) vs. 

Mean Reservoir Depth (ft)

• Number of Reservoirs in Oil Accumulations vs. API 

Gravity (Degrees)

If data are insufficient or do not exist, graphs are not provided. Therefore, not all graphs are included in all files.
4 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

File List

Data Tables

eco5034.tab

fed5034.tab

inf5034.tab

ins5034.tab

kvol5034.tab

own5034.tab

sta5034.tab

vol5034.tab

Summary Tables Assessment-Unit Name

c340101.pdf Paleozoic-Mesozoic

 Conventional Oil and Gas

c340201.pdf Cretaceous-Tertiary

 Conventional Oil and Gas

d340101.pdf Paleozoic-Mesozoic

 Conventional Oil and Gas

d340201.pdf Cretaceous-Tertiary

 Conventional Oil and Gas

u340261.pdf Muddy-Frontier Sandstone

 and Mowry Fractured Shale

 Continuous Gas

u340262.pdf Mowry Fractured Shale

 Continuous Oil

u340263.pdf Cody Sandstone Continuous

 Gas

u340264.pdf Mesaverde Sandstone

 Continuous Gas

u340281.pdf Mesaverde-Meeteetse

 Formation Coalbed Gas

u340282.pdf Fort Union Formation

 Coalbed Gas

Graphs Assessment-Unit Name

em340101.pdf Paleozoic-Mesozoic

 Conventional Oil and Gas

em340201.pdf Cretaceous-Tertiary

 Conventional Oil and Gas

fp340261.pdf Muddy-Frontier Sandstone

 and Mowry Fractured Shale

 Continuous Gas

fp340262.pdf Mowry Fractured Shale

 Continuous Oil

fp340263.pdf Cody Sandstone Continuous

 Gas

fp340264.pdf Mesaverde Sandstone

 Continuous Gas

fp340281.pdf Mesaverde-Meeteetse

 Formation Coalbed Gas

g340101.pdf Paleozoic-Mesozoic

 Conventional Oil and Gas

g340201.pdf Cretaceous-Tertiary

 Conventional Oil and Gas

k340101.pdf Paleozoic-Mesozoic

 Conventional Oil and Gas

k340201.pdf Cretaceous-Tertiary

 Conventional Oil and Gas

Tabular Data

The eco####.tab, fed####.tab, own####.tab, and sta####.

tab files contain volume-percent data of undiscovered petroleum allocated to ecosystem regions, Federal lands, general 

land-ownership parcels, and States. Cells are left blank if data 

are unavailable.

The eco####.tab table contains 59 columns. The sum of 

the percentages should equal those for the total area (excluding offshore) in the own####.tab file. Data columns for these 

files are as follows:

1. Code—assessment-unit code number.

2. Name—assessment-unit name.

3. Area km2—area of the assessment unit in square 

kilometers.

4. Eco 1—name of first ecosystem that occupies all or 

part of the assessment-unit area.

5. E1 Area %—percentage of assessment-unit area that 

is occupied by ecosystem 1.

6. E1 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 1.

7. E1 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 1.

8. Eco 2—name of second ecosystem that occupies part 

of the assessment-unit area.

9. E2 Area %—percentage of assessment-unit area that 

is occupied by ecosystem 2.

10. E2 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 2.

11. E2 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 2.

12. Eco 3—name of third ecosystem that occupies part 

of the assessment-unit area.

13. E3 Area %—percentage of assessment-unit area that 

is occupied by ecosystem 3.

14. E3 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 3.

15. E3 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 3.
Tabular Data 5

16. Eco 4—name of fourth ecosystem that occupies part 

of the assessment-unit area.

17. E4 Area %—percentage of assessment-unit area that 

is occupied by ecosystem 4.

18. E4 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 4.

19. E4 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 4.

20. Eco 5—name of fifth ecosystem that occupies part of 

the assessment-unit area.

21. E5 Area %—percentage of assessment-unit area that 

is occupied by ecosystem 5.

22. E5 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 5.

23. E5 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 5.

24. Eco 6—name of sixth ecosystem that occupies part 

of the assessment-unit area.

25. E6 Area %—percentage of assessment-unit area that 

is occupied by ecosystem 6.

26. E6 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 6.

27. E6 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 6.

28. Eco 7—name of seventh ecosystem that occupies 

part of the assessment-unit area.

29. E7 Area %— percentage of assessment-unit area that 

is occupied by ecosystem 7.

30. E7 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 7.

31. E7 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 7.

32. Eco 8—name of eighth ecosystem that occupies part 

of the assessment-unit area.

33. E8 Area %—percentage of assessment-unit area that 

is occupied by ecosystem 8.

34. E8 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 8.

35. E8 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 8.

36. Eco 9—name of ninth ecosystem that occupies part 

of the assessment-unit area.

37. E9 Area %—percentage of assessment-unit area that 

is occupied by ecosystem 9.

38. E9 Oil %—estimated percentage of undiscovered oil 

volume allocated to ecosystem 9.

39. E9 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 9.

40. Eco 10—name of tenth ecosystem that occupies part 

of the assessment-unit area.

41. E10 Area %—percentage of assessment-unit area 

that is occupied by ecosystem 10.

42. E10 Oil %—estimated percentage of undiscovered 

oil volume allocated to ecosystem 10.

43. E10 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 10.

44. Eco 11—name of eleventh ecosystem that occupies 

part of the assessment-unit area.

45. E11 Area %—percentage of assessment-unit area 

that is occupied by ecosystem 11.

46. E11 Oil %—estimated percentage of undiscovered 

oil volume allocated to ecosystem 11.

47. E11 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 11.

48. Eco 12—name of twelfth ecosystem that occupies 

part of the assessment-unit area.

49. E12 Area %—percentage of assessment-unit area 

that is occupied by ecosystem 12.

50. E12 Oil %—estimated percentage of undiscovered 

oil volume allocated to ecosystem 12.

51. E12 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 12.

52. Eco 13—name of thirteenth ecosystem that occupies 

part of the assessment-unit area.

53. E13 Area %—percentage of assessment-unit area 

that is occupied by ecosystem 13.

54. E13 Oil %—estimated percentage of undiscovered 

oil volume allocated to ecosystem 13.

55. E13 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 13.

56. Eco 14—name of fourteenth ecosystem that occupies part of the assessment-unit area.

57. E14 Area %—percentage of assessment-unit area 

that is occupied by ecosystem 14.

58. E14 Oil %—estimated percentage of undiscovered 

oil volume allocated to ecosystem 14.

59. E14 Gas %—estimated percentage of undiscovered 

gas volume allocated to ecosystem 14.
6 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

The fed####.tab table contains 83 columns. The sum of 

the percentages should equal those for Federal lands in the 

own####.tab file. Data columns for these files are:

1. Code—assessment-unit code number.

2. Name—assessment-unit name.

3. Area km2—area of the assessment unit in square 

kilometers.

4. BLM—“Bureau of Land Management (BLM),” 

name of Federal land that occupies all or part of the 

assessment-unit area.

5. BLM Area %—percentage of assessment-unit area 

that is occupied by Bureau of Land Management 

lands.

6. BLM Oil %—estimated percentage of undiscovered 

oil volume allocated to Bureau of Land Management 

lands.

7. BLM Gas %—estimated percentage of undiscovered 

gas volume allocated to Bureau of Land Management lands.

8. BLMW—“BLM Wilderness Areas (BLMW),” 

name of Federal land that occupies all or part of the 

assessment-unit area.

9. BLMW Area %—percentage of assessment-unit area 

that is occupied by Bureau of Land Management 

Wilderness Areas.

10. BLMW Oil %—estimated percentage of undiscovered oil volume allocated to Bureau of Land Management Wilderness Areas.

11. BLMW Gas %—estimated percentage of undiscovered gas volume allocated to Bureau of Land 

Management Wilderness Areas.

12. BLMR—“BLM Roadless Areas (BLMR),” name of 

Federal land that occupies all or part of the assessment-unit area.

13. BLMR Area %—percentage of assessment-unit area 

that is occupied by Bureau of Land Management 

Roadless Areas.

14. BLMR Oil %—estimated percentage of undiscovered oil volume allocated to Bureau of Land Management Roadless Areas.

15. BLMR Gas %—estimated percentage of undiscovered gas volume allocated to Bureau of Land 

Management Roadless Areas.

16. NPS—“National Park Service (NPS),” name of Federal land that occupies all or part of the assessmentunit area.

17. NPS Area %—percentage of assessment-unit area 

that is occupied by National Park Service lands.

18. NPS Oil %—estimated percentage of undiscovered 

oil volume allocated to National Park Service lands.

19. NPS Gas %—estimated percentage of undiscovered 

gas volume allocated to National Park Service lands.

20. NPSW—“NPS Wilderness Areas (NPSW),” name of 

Federal land that occupies all or part of the assessment-unit area.

21. NPSW Area %—percentage of assessment-unit area 

that is occupied by National Park Service Wilderness 

Areas.

22. NPSW Oil %—estimated percentage of undiscovered oil volume allocated to National Park Service 

Wilderness Areas.

23. NPSW Gas %—estimated percentage of undiscovered gas volume allocated to National Park Service 

Wilderness Areas

24. NPSP—“NPS Withdrawals (NPSP),” name of Federal land that occupies all or part of the assessmentunit area.

25. NPSP Area %—percentage of assessment-unit area 

that is occupied by National Park Service Withdrawals.

26. NPSP Oil %—estimated percentage of undiscovered oil volume allocated to National Park Service 

Withdrawals.

27. NPSP Gas %—estimated percentage of undiscovered gas volume allocated to National Park Service 

Withdrawals.

28. FS—“Forest Service (FS),” name of Federal land 

that occupies all or part of the assessment-unit area.

29. FS Area %—percentage of assessment-unit area that 

is occupied by USDA Forest Service lands.

30. FS Oil %—estimated percentage of undiscovered oil 

volume allocated to USDA Forest Service lands.

31. FS Gas %—estimated percentage of undiscovered 

gas volume allocated to USDA Forest Service lands.

32. FSW—“FS Wilderness Areas (FSW),” name of Federal land that occupies all or part of the assessmentunit area.

33. FSW Area %—percentage of assessment-unit area 

that is occupied by USDA Forest Service Wilderness 

Areas.

34. FSW Oil %—estimated percentage of undiscovered 

oil volume allocated to USDA Forest Service Wilderness Areas.

35. FSW Gas %—estimated percentage of undiscovered gas volume allocated to USDA Forest Service 

Wilderness Areas.
Tabular Data 7

36. FSR—“FS Roadless Areas (FSR),” name of Federal 

land that occupies all or part of the assessment-unit 

area.

37. FSR Area %—percentage of assessment-unit area 

that is occupied by USDA Forest Service Roadless 

Areas.

38. FSR Oil %—estimated percentage of undiscovered 

oil volume allocated to USDA Forest Service Roadless Areas.

39. FSR Gas %—estimated percentage of undiscovered 

gas volume allocated to USDA Forest Service Roadless Areas.

40. FSP—“FS Protected Withdrawals (FSP),” name of 

Federal land that occupies all or part of the assessment-unit area.

41. FSP Area %—percentage of assessment-unit area 

that is occupied by USDA Forest Service Protected 

Withdrawals.

42. FSP Oil %—estimated percentage of undiscovered 

oil volume allocated to USDA Forest Service Protected Withdrawals.

43. FSP Gas %—estimated percentage of undiscovered 

gas volume allocated to USDA Forest Service Protected Withdrawals.

44. FWS—“U.S. Fish and Wildlife Service (USFWS),” 

name of Federal land that occupies all or part of the 

assessment-unit area.

45. FWS Area %—percentage of assessment-unit area 

that is occupied by U.S. Fish and Wildlife Service 

lands.

46. FWS Oil %—estimated percentage of undiscovered oil volume allocated to U.S. Fish and Wildlife 

Service lands.

47. FWS Gas %—estimated percentage of undiscovered gas volume allocated to U.S. Fish and Wildlife 

Service lands.

48. FWSW—“USFWS Wilderness Areas (USFWSW),” 

name of Federal land that occupies all or part of the 

assessment-unit area.

49. FWSW Area %—percentage of assessment-unit area 

that is occupied by U.S. Fish and Wildlife Service 

Wilderness Areas.

50. FWSW Oil %—estimated percentage of undiscovered oil volume allocated to U.S. Fish and Wildlife 

Service Wilderness Areas.

51. FWSW Gas %—estimated percentage of undiscovered gas volume allocated to U.S. Fish and Wildlife 

Service Wilderness Areas.

52. FWSP—“USFWS Protected Withdrawals (USFWSP),” name of Federal land that occupies all or 

part of the assessment-unit area.

53. FWSP Area %—percentage of assessment-unit area 

that is occupied by U.S. Fish and Wildlife Service 

Protected Withdrawals.

54. FWSP Oil %—estimated percentage of undiscovered oil volume allocated to U.S. Fish and Wildlife 

Service Protected Withdrawals.

55. FWSP Gas %—estimated percentage of undiscovered gas volume allocated to U.S. Fish and Wildlife 

Service Protected Withdrawals.

56. WS—“Wilderness Study Areas (WS),” name of Federal land that occupies all or part of the assessmentunit area.

57. WS Area %—percentage of assessment-unit area 

that is occupied by Wilderness Study Areas.

58. WS Oil %—estimated percentage of undiscovered 

oil volume allocated to Wilderness Study Areas.

59. WS Gas %—estimated percentage of undiscovered 

gas volume allocated to Wilderness Study Areas.

60. DOE—“Department of Energy (DOE),” name of 

Federal land that occupies all or part of the assessment-unit area.

61. DOE Area %—percentage of assessment-unit area 

that is occupied by Department of Energy lands.

62. DOE Oil %—estimated percentage of undiscovered 

oil volume allocated to Department of Energy lands.

63. DOE Gas %—estimated percentage of undiscovered 

gas volume allocated to Department of Energy lands.

64. DOD—“Department of Defense (DOD),” name of 

Federal land that occupies all or part of the assessment-unit area.

65. DOD Area %—percentage of assessment-unit area 

that is occupied by Department of Defense lands.

66. DOD Oil %—estimated percentage of undiscovered oil volume allocated to Department of Defense 

lands.

67. DOD Gas %—estimated percentage of undiscovered 

gas volume allocated to Department of Defense 

lands.

68. BOR—“Bureau of Reclamation (BOR),” name of 

Federal land that occupies all or part of the assessment-unit area.

69. BOR Area %—percentage of assessment-unit area 

that is occupied by Bureau of Reclamation lands.

70. BOR Oil %—estimated percentage of undiscovered 

oil volume allocated to Bureau of Reclamation lands.
8 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

71. BOR Gas %—estimated percentage of undiscovered 

gas volume allocated to Bureau of Reclamation 

lands.

72. TVA—“Tennessee Valley Authority (TVA),” name 

of Federal land that occupies all or part of the 

assessment-unit area.

73. TVA Area %—percentage of assessment-unit area 

that is occupied by Tennessee Valley Authority 

lands.

74. TVA Oil %—estimated percentage of undiscovered 

oil volume allocated to Tennessee Valley Authority 

lands.

75. TVA Gas %—estimated percentage of undiscovered 

gas volume allocated to Tennessee Valley Authority 

lands.

76. Other—“Other Federal,” other unspecified Federal 

lands that occupy all part of the assessment-unit 

area.

77. Oth Area %—percentage of assessment-unit area 

that is occupied by other unspecified Federal lands.

78. Oth Oil %—estimated percentage of undiscovered 

oil volume allocated to other unspecified Federal 

lands.

79. Oth Gas %—estimated percentage of undiscovered 

gas volume allocated to other unspecified Federal 

lands.

80. Fed 20—name of additional specified Federal lands 

that occupy all or part of the assessment-unit area.

81. F20 Area %—percentage of assessment-unit area 

that is occupied by additional specified Federal 

lands.

82. F20 Oil %—estimated percentage of undiscovered 

oil volume allocated to additional specified Federal 

lands.

83. F20 Gas %—estimated percentage of undiscovered 

gas volume allocated to additional specified Federal 

lands.

The own####.tab table contains 59 columns. The sum of 

the percentages should equal 100. Data columns for these files 

are as follows:

1. Code—assessment-unit code number.

2. Name—assessment-unit name.

3. Area km2—area of the assessment unit in square 

kilometers.

4. Fed—“Federal Lands,” all Federal lands that occupy 

all or part of the assessment-unit area.

5. Fed Area %—percentage of assessment-unit area 

that is occupied by Federal lands.

6. Fed Oil %—estimated percentage of undiscovered 

oil volume allocated to Federal lands.

7. Fed Gas %—estimated percentage of undiscovered 

gas volume allocated to Federal lands.

8. Pri—“Private Lands,” all private lands that occupy 

all or part of the assessment-unit area.

9. Pri Area %—percentage of assessment-unit area that 

is occupied by private lands.

10. Pri Oil %—estimated percentage of undiscovered oil 

volume allocated to private lands.

11. Pri Gas %—estimated percentage of undiscovered 

gas volume allocated to private lands.

12. Tri—“Tribal Lands,” all tribal lands that occupy all 

or part of the assessment-unit area.

13. Tri Area %—percentage of assessment-unit area that 

is occupied by tribal lands.

14. Tri Oil %—estimated percentage of undiscovered oil 

volume allocated to tribal lands.

15. Tri Gas %—estimated percentage of undiscovered 

gas volume allocated to tribal lands.

16. Oth—name of other unspecified lands or offshore 

areas that occupy all or part of the assessment-unit 

area.

17. Oth Area %—percentage of assessment-unit area 

that is occupied by other unspecified lands or offshore areas.

18. Oth Oil %—estimated percentage of undiscovered 

oil volume allocated to other unspecified lands or 

offshore areas.

19. Oth Gas %—estimated percentage of undiscovered 

gas volume allocated to other unspecified lands or 

offshore areas.

20. State 1—name of first State for which State-owned 

lands or waters occupy all or part of the assessmentunit area.

21. S1 Area %—percentage of assessment-unit area that 

is occupied by State 1-owned lands or waters.

22. S1 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 1-owned lands or waters.

23. S1 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 1-owned lands or 

waters.

24. State 2—name of second State for which Stateowned lands or waters occupy all or part of the 

assessment-unit area.

25. S2 Area %—percentage of assessment-unit area that 

is occupied by State 2-owned lands or waters.
Tabular Data 9

26. S2 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 2-owned lands or waters.

27. S2 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 2-owned lands or 

waters.

28. State 3—name of third State for which State-owned 

lands or waters occupy all or part of the assessmentunit area.

29. S3 Area %—percentage of assessment-unit area that 

is occupied by State 3-owned lands or waters.

30. S3 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 3-owned lands or waters.

31. S3 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 3-owned lands or 

waters.

32. State 4—name of fourth State for which State-owned 

lands or waters occupy all or part of the assessmentunit area.

33. S4 Area %—percentage of assessment-unit area that 

is occupied by State 4-owned lands or waters.

34. S4 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 4-owned lands or waters.

35. S4 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 4-owned lands or 

waters.

36. State 5—name of fifth State for which State-owned 

lands or waters occupy all or part of the assessmentunit area.

37. S5 Area %—percentage of assessment-unit area that 

is occupied by State 5-owned lands or waters.

38. S5 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 5-owned lands or waters.

39. S5 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 5-owned lands or 

waters.

40. State 6—name of sixth State for which State-owned 

lands or waters occupy all or part of the assessmentunit area.

41. S6 Area %—percentage of assessment-unit area that 

is occupied by State 6-owned lands or waters.

42. S6 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 6-owned lands or waters.

43. S6 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 6-owned lands or 

waters.

44. State 7—name of seventh State for which Stateowned lands or waters occupy all or part of the 

assessment-unit area.

45. S7 Area %—percentage of assessment-unit area that 

is occupied by State 7-owned lands or waters.

46. S7 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 7-owned lands or waters.

47. S7 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 7-owned lands or 

waters.

48. State 8—name of eighth State for which Stateowned lands or waters occupy all or part of the 

assessment-unit area.

49. S8 Area %—percentage of assessment-unit area that 

is occupied by State 8-owned lands or waters.

50. S8 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 8-owned lands or waters.

51. S8 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 8-owned lands or 

waters.

52. State 9—name of ninth State for which State-owned 

lands or waters occupy all or part of the assessmentunit area.

53. S9 Area %—percentage of assessment-unit area that 

is occupied by State 9-owned lands or waters.

54. S9 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 9-owned lands or waters.

55. S9 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 9-owned lands or 

waters.

56. State 10—name of tenth State for which Stateowned lands or waters occupy all or part of the 

assessment-unit area.

57. S10 Area %—percentage of assessment-unit area 

that is occupied by State 10-owned lands or waters.

58. S10 Oil %—estimated percentage of undiscovered 

oil volume allocated to State 10-owned lands or 

waters.

59. S10 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 10-owned lands or 

waters.

The sta####.tab table contains 59 columns. The sum of 

the percentages should equal 100. Data columns for these files 

are as follows:

1. Code—assessment-unit code number.

2. Name—assessment-unit name.

3. Area km2—area of the assessment unit in square 

kilometers.

4. State 1—name of first State (onshore and offshore) 

that occupies all or part of the assessment-unit area.
10 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

5. S1 Area %—percentage of assessment-unit area that 

is occupied by State 1.

6. S1 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 1.

7. S1 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 1.

8. State 2—name of second State (onshore and offshore) that occupies all or part of the assessment-unit 

area.

9. S2 Area %—percentage of assessment-unit area that 

is occupied by State 2.

10. S2 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 2.

11. S2 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 2.

12. State 3—name of third State (onshore and offshore) 

that occupies all or part of the assessment-unit area.

13. S3 Area %—percentage of assessment-unit area that 

is occupied by State 3.

14. S3 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 3.

15. S3 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 3.

16. State 4—name of fourth State (onshore and offshore) 

that occupies all or part of the assessment-unit area.

17. S4 Area %—percentage of assessment-unit area that 

is occupied by State 4.

18. S4 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 4.

19. S4 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 4.

20. State 5—name of fifth State (onshore and offshore) 

that occupies all or part of the assessment-unit area.

21. S5 Area %—percentage of assessment-unit area that 

is occupied by State 5.

22. S5 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 5.

23. S5 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 5.

24. State 6—name of sixth State (onshore and offshore) 

that occupies all or part of the assessment-unit area.

25. S6 Area %—percentage of assessment-unit area that 

is occupied by State 6.

26. S6 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 6.

27. S6 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 6.

28. State 7—name of seventh State (onshore and offshore) that occupies all or part of the assessment-unit 

area.

29. S7 Area %—percentage of assessment-unit area that 

is occupied by State 7.

30. S7 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 7.

31. S7 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 7.

32. State 8—name of eighth State (onshore and offshore) that occupies all or part of the assessment-unit 

area.

33. S8 Area %—percentage of assessment-unit area that 

is occupied by State 8.

34. S8 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 8.

35. S8 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 8.

36. State 9—name of ninth State (onshore and offshore) 

that occupies all or part of the assessment-unit area.

37. S9 Area %—percentage of assessment-unit area that 

is occupied by State 9.

38. S9 Oil %—estimated percentage of undiscovered oil 

volume allocated to State 9.

39. S9 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 9.

40. State 10—name of tenth State (onshore and offshore) that occupies all or part of the assessment-unit 

area.

41. S10 Area %—percentage of assessment-unit area 

that is occupied by State 10.

42. S10 Oil %—estimated percentage of undiscovered 

oil volume allocated to State 10.

43. S10 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 10.

44. State 11—name of eleventh State (onshore and 

offshore) that occupies all or part of the assessmentunit area.

45. S11 Area %—percentage of assessment-unit area 

that is occupied by State 11.

46. S11 Oil %—estimated percentage of undiscovered 

oil volume allocated to State 11.

47. S11 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 11.
Tabular Data 11

48. State 12—name of twelfth State (onshore and offshore) that occupies all or part of the assessment-unit 

area.

49. S12 Area %—percentage of assessment-unit area 

that is occupied by State 12.

50. S12 Oil %—estimated percentage of undiscovered 

oil volume allocated to State 12.

51. S12 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 12.

52. State 13—name of thirteenth State (onshore and 

offshore) that occupies all or part of the assessmentunit area.

53. S13 Area %—percentage of assessment-unit area 

that is occupied by State 13.

54. S13 Oil %—estimated percentage of undiscovered 

oil volume allocated to State 13.

55. S13 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 13.

56. State 14—name of fourteenth State (onshore and 

offshore) that occupies all or part of the assessmentunit area.

57. S14 Area %—percentage of assessment-unit area 

that is occupied by State 14.

58. S14 Oil %—estimated percentage of undiscovered 

oil volume allocated to State 14.

59. S14 Gas %—estimated percentage of undiscovered 

gas volume allocated to State 14.

The vol####.tab table contains estimates of undiscovered petroleum resources along with parameters that express 

uncertainty in these estimates. The table contains 40 columns. 

Blank cells represent no data. Data columns for these files are 

as follows:

1. Code—assessment-unit code number.

2. Name—assessment-unit name.

3. Type—type of assessment unit, conventional, continuous oil, continuous gas, or coalbed gas.

4. Status—remarks indicating that assessment unit was 

not quantitatively assessed; otherwise blank.

5. Prob %—geologic probability of the assessment 

unit.

6. OILF95 MMB—the estimated value of undiscovered oil (oil in oil accumulations) such that there is 

a 95-percent probability that this amount or more 

exists in the assessment unit. The volume is given in 

millions of barrels of oil (MMBO).

7. OILF50 MMB—the estimated value of undiscovered oil (oil in oil accumulations) such that there is 

a 50-percent probability that this amount or more 

exists in the assessment unit. This is the median 

value. The volume is given in millions of barrels of 

oil (MMBO).

8. OILF5 MMB—the estimated value of undiscovered 

oil (oil in oil accumulations) such that there is a 

5-percent probability that this amount or more exists 

in the assessment unit. The volume is given in millions of barrels of oil (MMBO).

9. OILMN MMB—the estimated mean (average) 

value of undiscovered oil (oil in oil accumulations). 

The volume is given in millions of barrels of oil 

(MMBO).

10. OILSD MMB—the estimated standard deviation 

value of undiscovered oil (oil in oil accumulations). 

The volume is given in millions of barrels of oil 

(MMBO).

11. AGF95 BCF—the estimated value of undiscovered 

associated/dissolved gas (gas in oil accumulations) 

such that there is a 95-percent probability that this 

amount or more exists in the assessment unit. The 

volume is given in billions of cubic feet of gas 

(BCFG).

12. AGF50 BCF—the estimated value of undiscovered 

associated/dissolved gas (gas in oil accumulations) 

such that there is a 50-percent probability that this 

amount or more exists in the assessment unit. This is 

the median value. The volume is given in billions of 

cubic feet of gas (BCFG).

13. AGF5 BCF—the estimated value of undiscovered 

associated/dissolved gas (gas in oil accumulations) 

such that there is a 5-percent probability that this 

amount or more exists in the assessment unit. The 

volume is given in billions of cubic feet of gas 

(BCFG).

14. AGMN BCF—the estimated mean (average) value 

of undiscovered associated/dissolved gas (gas in oil 

accumulations). The volume is given in billions of 

cubic feet of gas (BCFG).

15. AGSD BCF—the estimated standard deviation value 

of undiscovered associated/dissolved gas (gas in oil 

accumulations). The volume is given in billions of 

cubic feet of gas (BCFG).

16. NGLF95 MMB—the estimated value of undiscovered natural gas liquids (NGL in oil accumulations) 

such that there is a 95-percent probability that 

this amount or more exists in the assessment unit. 

The volume is given in millions of barrels of NGL 

(MMBNGL).

17. NGLF50 MMB—the estimated value of undiscovered natural gas liquids (NGL in oil accumulations) 

such that there is a 50-percent probability that this 

amount or more exists in the assessment unit. This is 

the median value. The volume is given in millions of 

barrels of NGL (MMBNGL).
12 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

18. NGLF5 MMB—the estimated value of undiscovered 

natural gas liquids (NGL in oil accumulations) such 

that there is a 5-percent probability that this amount 

or more exists in the assessment unit. The volume is 

given in millions of barrels of NGL (MMBNGL).

19. NGLMN MMB—the estimated mean (average) 

value of undiscovered natural gas liquids (NGL in 

oil accumulations). The volume is given in millions 

of barrels of NGL (MMBNGL).

20. NGLSD MMB—the estimated standard deviation 

value of undiscovered natural gas liquids (NGL in 

oil accumulations). The volume is given in millions 

of barrels of NGL (MMBNGL).

21. NGF95 BCF—the estimated value of undiscovered 

nonassociated gas (gas in gas accumulations) such 

that there is a 95-percent probability that this amount 

or more exists in the assessment unit. The volume is 

given in billions of cubic feet of gas (BCFG).

22. NGF50 BCF—the estimated value of undiscovered 

nonassociated gas (gas in gas accumulations) such 

that there is a 50-percent probability that this amount 

or more exists in the assessment unit. This is the 

median value. The volume is given in billions of 

cubic feet of gas (BCFG).

23. NGF5 BCF—the estimated value of undiscovered 

nonassociated gas (gas in gas accumulations) such 

that there is a 5-percent probability that this amount 

or more exists in the assessment unit. The volume is 

given in billions of cubic feet of gas (BCFG).

24. NGMN BCF—the estimated mean (average) value 

of undiscovered nonassociated gas (gas in gas accumulations). The volume is given in billions of cubic 

feet of gas (BCFG).

25. NGSD BCF—the estimated standard deviation value 

of undiscovered nonassociated gas (gas in gas accumulations). The volume is given in billions of cubic 

feet of gas (BCFG).

26. LIQF95 MMB—the estimated value of undiscovered 

liquids (oil and NGL in gas accumulations) such that 

there is a 95-percent probability that this amount or 

more exists in the assessment unit. The volume is 

given in millions of barrels of liquids (MMBL).

27. LIQF50 MMB—the estimated value of undiscovered 

liquids (oil and NGL in gas accumulations) such that 

there is a 50-percent probability that this amount 

or more exists in the assessment unit. This is the 

median value. The volume is given in millions of 

barrels of liquids (MMBL).

28. LIQF5 MMB—the estimated value of undiscovered 

liquids (oil and NGL in gas accumulations) such that 

there is a 5-percent probability that this amount or 

more exists in the assessment unit. The volume is 

given in millions of barrels of liquids (MMBL).

29. LIQMN MMB—the estimated mean (average) value 

of undiscovered liquids (oil and NGL in gas accumulations). The volume is given in millions of barrels 

of liquids (MMBL).

30. LIQSD MMB—the estimated standard deviation 

value of undiscovered liquids (oil and NGL in gas 

accumulations). The volume is given in millions of 

barrels of liquids (MMBL).

31. LOF95 MMB—the estimated size of the largest 

undiscovered conventional oil accumulation such 

that there is a 95-percent probability of that accumulation being this amount or larger. The volume is 

given in millions of barrels of oil (MMBO).

32. LOF50 MMB—the estimated size of the largest 

undiscovered conventional oil accumulation such 

that there is a 50-percent probability of that accumulation being this amount or larger. This is the median 

value. The volume is given in millions of barrels of 

oil (MMBO).

33. LOF5 MMB—the estimated size of the largest 

undiscovered conventional oil accumulation such 

that there is a 5-percent probability of that accumulation being this amount or larger. The volume is given 

in millions of barrels of oil (MMBO).

34. LOMN MMB—the estimated mean (average) value 

of the largest undiscovered conventional oil accumulation. The volume is given in millions of barrels of 

oil (MMBO).

35. LOSD MMB—the estimated standard deviation 

value of the largest undiscovered conventional oil 

accumulation. The volume is given in millions of 

barrels of oil (MMBO).

36. LGF95 BCF—the estimated size of the largest 

undiscovered conventional gas accumulation such 

that there is a 95-percent probability of that accumulation being this amount or larger. The volume is 

given in billions of cubic feet of gas (BCFG).

37. LGF50 BCF—the estimated size of the largest 

undiscovered conventional gas accumulation such 

that there is a 50-percent probability of that accumulation being this amount or larger. This is the median 

value. The volume is given in billions of cubic feet 

of gas (BCFG).

38. LGF5 BCF—the estimated size of the largest undiscovered conventional gas accumulation such that 

there is a 5-percent probability of that accumulation 

being this amount or larger. The volume is given in 

billions of cubic feet of gas (BCFG).

39. LGMN BCF—the estimated mean (average) value 

of the largest undiscovered conventional gas accumulation. The volume is given in billions of cubic 

feet of gas (BCFG).
Tabular Data 13

40. LGSD BCF—the estimated standard deviation value 

of the largest undiscovered conventional gas accumulation. The volume is given in billions of cubic 

feet of gas (BCFG).

The inf####.tab table contains input data from the FORSPAN Assessment Model for Continuous Accumulations–Basic 

Input Data Form used in this assessment and provided in the 

u######.pdf files. Cells are left blank if data are unavailable. 

This table contains 98 columns. Data columns are:

1. Date—date of assessment.

2. Geol—assessing geologist’s name.

3. Regno—region code number.

4. Reg—region name.

5. Provno—province code number.

6. Prov—province name.

7. TPSno—total petroleum system code number.

8. TPS—total petroleum system name.

9. AUno—assessment-unit code number.

10. AU—assessment-unit name.

11. Data1—data sources used to aid in completing the 

data-input form.

12. Data2—continuation of data sources used to aid in 

completing the data-input form.

13. Comm—assessment unit type, the primary commodity type in the assessment unit, based on the 

gas-to-oil ratio of the petroleum endowment, which 

includes both the discovered and undiscovered 

petroleum. An assessment unit is characterized as 

being oil prone if the gas-to-oil ratio is less than 

20,000 cubic feet of gas per barrel of oil; otherwise, 

it is gas prone.

14. RminMMBBCF—minimum total recovery per cell 

considered for assessment, in million barrels of oil 

(MMBO) for oil assessment units or billion cubic 

feet of gas (BCFG) for gas assessment units.

15. Numtest1—number of tested cells in the assessment 

unit.

16. Numtest2—number of tested cells in the assessment 

unit that have total recoveries equal to or larger than 

the specified minimum total recovery per cell.

17. AUM—assessment-unit maturity, the exploration 

maturity of the assessment unit. Assessment-unit 

maturity is classified as “established” if more than 24 

cells exceed the minimum total recovery, “frontier” 

if 1 to 24 cells exceed the minimum total recovery, 

or “hypothetical” if no cells exceed the minimum 

total recovery.

18. Med1MMBBCF—median total recovery per cell 

of the set of tested cells equal to or greater than 

the minimum total recovery that constitute the first 

one-third of the total number of cells ranked according to date of discovery within the assessment unit, 

in million barrels of oil (MMBO) for oil assessment 

units or billion cubic feet of gas (BCFG) for gas 

assessment units.

19. Med2MMBBCF—median total recovery per cell 

of the set of tested cells equal to or greater than the 

minimum total recovery that constitute the second 

one-third of the total number of cells ranked according to date of discovery within the assessment unit, 

in million barrels of oil (MMBO) for oil assessment 

units or billion cubic feet of gas (BCFG) for gas 

assessment units.

20. Med3MMBBCF—median total recovery per cell 

of the set of tested cells equal to or greater than the 

minimum total recovery that constitute the third 

one-third of the total number of cells ranked according to date of discovery within the assessment unit, 

in million barrels of oil (MMBO) for oil assessment 

units or billion cubic feet of gas (BCFG) for gas 

assessment units.

21. Prob1 %—charge probability, the probability for 

adequate petroleum charge for at least one untested 

cell equal to or larger than the minimum total recovery, somewhere in the assessment unit, having the 

potential to be added to reserves in the next 30 years. 

Charge probability is given as a fractional value 

from 0 to 1.0.

22. Prob2 %—rocks probability, the probability for 

adequate reservoirs, traps, and seals for at least one 

untested cell equal to or larger than the minimum 

total recovery, somewhere in the assessment unit, 

having the potential to be added to reserves in the 

next 30 years. Rocks probability is given as a fractional value from 0 to 1.0.

23. Prob3 %—timing probability, the probability for 

favorable geologic timing for at least one untested 

cell equal to or larger than the minimum total recovery, somewhere in the assessment unit, having the 

potential to be added to reserves in the next 30 years. 

Timing probability is given as a fractional value 

from 0 to 1.0.

24. Geoprob %—geologic probability, the product of 

charge, rocks, and timing probabilities. Geologic 

probability is given as a fractional value from 0 to 

1.0.

25. TAAmin a—minimum total assessment-unit area, 

the estimated minimum (F100) area of the assessment unit. The area is given in acres.

26. TAAmod a—mode of total assessment-unit area, the 

estimated modal area of the assessment unit. The 

area is given in acres.
14 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

27. TAAmax a—maximum total assessment-unit area, 

the estimated maximum (F0) area of the assessment 

unit. The area is given in acres.

28. TAAmean a—mean of total assessment-unit area, 

the calculated mean area of the assessment unit. The 

area is given in acres.

29. CAmin a—minimum area per cell of untested cells 

with potential, the estimated minimum (F100) area 

per cell of untested cells having the potential for 

additions to reserves in the specified timeframe for 

the assessment (30 years for this assessment) in the 

assessment unit. This area is equivalent to the drainage areas of wells. This area is given in acres.

30. CAmod a—mode of area per cell of untested cells 

with potential, the estimated modal area per cell of 

untested cells having the potential for additions to 

reserves in the specified timeframe for the assessment (30 years for this assessment) in the assessment 

unit. This area is equivalent to the drainage areas of 

wells. This area is given in acres.

31. CAmax a—maximum area per cell of untested cells 

with potential, the estimated maximum (F0) area 

per cell of untested cells having the potential for 

additions to reserves in the specified timeframe for 

the assessment (30 years for this assessment) in the 

assessment unit. This area is equivalent to the drainage areas of wells. This area is given in acres.

32. CAmean a—mean area per cell of untested cells 

with potential, the calculated mean area per cell of 

untested cells having the potential for additions to 

reserves in the specified timeframe for the assessment (30 years for this assessment) in the assessment 

unit. This area is equivalent to the drainage areas of 

wells. This area is given in acres.

33. CAminmn a—minimum calculated mean of the area 

per cell of untested cells with potential, the minimum uncertainty of the calculated mean area per cell 

of untested cells having the potential for additions to 

reserves in the specified timeframe for the assessment (30 years for this assessment) in the assessment 

unit. This area is equivalent to the drainage areas of 

wells. This area is given in acres.

34. CAmaxmn a—maximum calculated mean of the area 

per cell of untested cells with potential, the maximum uncertainty of the calculated mean area per cell 

of untested cells having the potential for additions to 

reserves in the specified timeframe for the assessment (30 years for this assessment) in the assessment 

unit. This area is equivalent to the drainage areas of 

wells. This area is given in acres.

35. TAAUmin %—estimated minimum (F100) percentage of the total assessment-unit area that is untested.

36. TAAUmod %—estimated median (F50) percentage 

of the total assessment-unit area that is untested.

37. TAAUmax %—estimated maximum (F0) percentage 

of the total assessment-unit area that is untested.

38. TAAUmean %—calculated mean percentage of the 

total assessment-unit area that is untested.

39. UAAPmin %—estimated minimum (F100) percentage of the untested area in the assessment unit 

having the potential for additions to reserves in the 

specified timeframe for the assessment (30 years for 

this assessment).

40. UAAPmod %—estimated median (F50) percentage 

of the untested area in the assessment unit having 

the potential for additions to reserves in the specified timeframe for the assessment (30 years for this 

assessment).

41. UAAPmax %—estimated maximum (F0) percentage 

of the untested area in the assessment unit having 

the potential for additions to reserves in the specified timeframe for the assessment (30 years for this 

assessment).

42. UAAPmean %—calculated mean percentage of 

the untested area in the assessment unit having the 

potential for additions to reserves in the specified 

timeframe for the assessment (30 years for this 

assessment).

43. RminMMBBCF—estimated minimum (F100) total 

recovery per cell for untested cells in the assessment 

unit having the potential for additions to reserves in 

the specified timeframe for the assessment (30 years 

for this assessment). This volume is given as million 

barrels of oil (MMBO) for oil assessment units and 

billion cubic feet of gas (BCFG) for gas assessment 

units.

44. RmedMMBBCF—estimated median (F50) total 

recovery per cell for untested cells in the assessment 

unit having the potential for additions to reserves in 

the specified timeframe for the assessment (30 years 

for this assessment). This volume is given as million 

barrels of oil (MMBO) for oil assessment units and 

billion cubic feet of gas (BCFG) for gas assessment 

units.

45. RmaxMMBBCF—estimated maximum (F0) total 

recovery per cell for untested cells in the assessment 

unit having the potential for additions to reserves in 

the specified timeframe for the assessment (30 years 

for this assessment). This volume is given as million 

barrels of oil (MMBO) for oil assessment units and 

billion cubic feet of gas (BCFG) for gas assessment 

units.

46. RmnMMBBCF—calculated mean total recovery per 

cell for untested cells in the assessment unit having 

the potential for additions to reserves in the specified timeframe for the assessment (30 years for this 

assessment). This volume is given as million barrels 

of oil (MMBO) for oil assessment units and billion 

cubic feet of gas (BCFG) for gas assessment units.
Tabular Data 15

47. GminCF/B—estimated minimum (F100) gas-to-oil 

ratio (GOR), in cubic feet of gas per barrel of oil 

(CFG/BO), of untested cells equal to or larger than 

the minimum total recovery in oil assessment units.

48. GmodCF/B—estimated mode of gas-to-oil ratio 

(GOR), in cubic feet of gas per barrel of oil (CFG/

BO), of untested cells equal to or larger than the 

minimum total recovery in oil assessment units.

49. GmaxCF/B—estimated maximum (F0) gas-to-oil 

ratio (GOR), in cubic feet of gas per barrel of oil 

(CFG/BO), of untested cells equal to or larger than 

the minimum total recovery in oil assessment units.

50. NminB/MMCF—estimated minimum (F100) natural 

gas liquids (NGL) to gas ratio, in barrels of natural 

gas liquids per million cubic feet of gas (BNGL/

MMCFG), of untested cells equal to or larger than 

the minimum total recovery in oil assessment units.

51. NmodB/MMCF—estimated mode of natural gas liquids (NGL) to gas ratio, in barrels of natural gas liquids per million cubic feet of gas (BNGL/MMCFG), 

of untested cells equal to or larger than the minimum 

total recovery in oil assessment units.

52. NmaxB/MMCF—estimated maximum (F0) natural 

gas liquids (NGL) to gas ratio, in barrels of natural 

gas liquids per million cubic feet of gas (BNGL/

MMCFG), of untested cells equal to or larger than 

the minimum total recovery in oil assessment units.

53. LminB/MMCF—estimated minimum (F100) liquids 

(oil plus natural gas liquids) to gas ratio (LGR), 

in barrels of liquids per million cubic feet of gas 

(BNGL/MMCFG), of untested cells equal to or 

larger than the minimum total recovery in gas assessment units.

54. LmodB/MMCF—estimated mode of liquids (oil 

plus natural gas liquids) to gas ratio (LGR), in barrels of liquids per million cubic feet of gas (BNGL/

MMCFG), of untested cells equal to or larger than 

the minimum total recovery in gas assessment units.

55. LmaxB/MMCF—estimated maximum (F0) liquids 

(oil plus natural gas liquids) to gas ratio (LGR), 

in barrels of liquids per million cubic feet of gas 

(BNGL/MMCFG), of untested cells equal to or 

larger than the minimum total recovery in gas assessment units.

56. APImin deg—estimated minimum (F100) API gravity, in degrees, of oil in untested cells in oil assessment units.

57. APImod deg—estimated mode of API gravity, in 

degrees, of oil in untested cells in oil assessment 

units.

58. APImax deg—estimated maximum (F0) API gravity, 

in degrees, of oil in untested cells in oil assessment 

units.

59. Smin %—estimated minimum (F100) sulfur content, 

in percent, of oil in untested cells in oil assessment 

units.

60. Smod %—estimated mode of sulfur content, in percent, of oil in untested cells in oil assessment units.

61. Smax %—estimated maximum (F0) sulfur content, 

in percent, of oil in untested cells in oil assessment 

units.

62. ODmin m—estimated minimum (F100) drilling 

depth, in meters, of oil in untested cells in oil assessment units.

63. ODf75 m—estimated 75th fractile (F75) of drilling 

depth, in meters, of oil in untested cells in oil assessment units.

64. ODmod m—estimated mode of drilling depth, in 

meters, of oil in untested cells in oil assessment 

units.

65. ODf25 m—estimated 25th fractile (F25) drilling 

depth, in meters, of oil in untested cells in oil assessment units.

66. ODmax m—estimated maximum (F0) drilling depth, 

in meters, of oil in untested cells in oil assessment 

units.

67. OWDmin m—estimated minimum (F100) water 

depth, in meters, of oil in untested cells in oil assessment units (ocean, bays, or lakes; if applicable).

68. OWDmod m—estimated mode of water depth, in 

meters, of oil in untested cells in oil assessment units 

(ocean, bays, or lakes; if applicable).

69. OWDmax m—estimated maximum (F0) water 

depth, in meters, of oil in untested cells in oil assessment units (ocean, bays, or lakes; if applicable).

70. IGmin %—estimated minimum (F100) inert gas 

content, in percent, of gas in untested cells in gas 

assessment units (nitrogen, helium, and so forth).

71. IGmod %—estimated mode of inert gas content, in 

percent, of gas in untested cells in gas assessment 

units (nitrogen, helium, and so forth).

72. IGmax %—estimated maximum (F0) inert gas 

content, in percent, of gas in untested cells in gas 

assessment units (nitrogen, helium, and so forth)(73)

CO2min %—estimated minimum (F100) carbon 

dioxide content, in percent, of gas in untested cells in 

gas assessment units.

73. CO2mod %—estimated mode of carbon dioxide 

content, in percent, of gas in untested cells in gas 

assessment units.

74. CO2max %—estimated maximum (F0) carbon dioxide content, in percent, of gas in untested cells in gas 

assessment units.
16 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

75. H2Smin %—estimated minimum (F100) hydrogen 

sulfide content, in percent, of gas in untested cells in 

gas assessment units.

76. H2Smod %—estimated mode of hydrogen sulfide 

content, in percent, of gas in untested cells in gas 

assessment units.

77. H2Smax %—estimated maximum (F0) hydrogen 

sulfide content, in percent, of gas in untested cells in 

gas assessment units.

78. HVmin btu—estimated minimum (F100) heating 

value of gas, in British Thermal Units, of gas in 

untested cells in gas assessment units.

79. HVmod btu—estimated mode of heating value of 

gas, in British Thermal Units, of gas in untested cells 

in gas assessment units.

80. HVmax btu—estimated maximum (F0) heating 

value of gas, in British Thermal Units, of gas in 

untested cells in gas assessment units.

81. GDmin m—estimated minimum (F100) drilling 

depth, in meters, of gas in untested cells in gas 

assessment units.

82. GDf25 m—estimated 25th fractile (F25) drilling 

depth, in meters, of gas in untested cells in gas 

assessment units.

83. GDmod m—estimated mode of drilling depth, in 

meters, of gas in untested cells in gas assessment 

units.

84. GDf25 m—estimated 25th fractile (F25) drilling 

depth, in meters, of gas in untested cells in gas 

assessment units.

85. GDmax m—estimated maximum (F0) drilling depth, 

in meters, of gas in untested cells in gas assessment 

units.

86. GWDmin m—estimated minimum (F100) water 

depth, in meters, of gas in untested cells in gas 

assessment units (ocean, bays, or lakes; if applicable).

87. GWDmod m—estimated mode of water depth, in 

meters, of gas in untested cells in gas assessment 

units (ocean, bays, or lakes; if applicable).

88. GWDmax m—estimated maximum (F0) water 

depth, in meters, of gas in untested cells in gas 

assessment units (ocean, bays, or lakes; if applicable).

89. FSRmean %—estimated mean future success ratio, 

as percent.

90. FSRmin %—estimated minimum (F100) future success ratio, as percent.

91. FSRmod %—estimated median (F50) future success 

ratio, as percent.

92. FSRmax %—estimated maximum (F0) future success ratio, as percent.

93. HSR %—historical success ratio, as percent.

94. TWCP—typical well-completion practice.

95. FWTS—fraction of wells drilled that are typically 

stimulated, as decimal fraction.

96. PST—predominant type of stimulation.

97. FHW—fraction of wells drilled that are horizontal, 

as decimal fraction.

The ins####.tab table contains input data from the Seventh Approximation Data Forms for Conventional Assessment 

Units used in this assessment and provided in the c######.

pdf files. Cells are left blank if data are unavailable. This table 

contains 78 columns. Data columns are as follows:

1. Date—date of assessment.

2. Geol—assessing geologist’s name.

3. Regno—region code number.

4. Reg—region name.

5. Provno—province code number.

6. Prov—province name.

7. TPSno—total petroleum system code number.

8. TPS—total petroleum system name.

9. AUno—assessment-unit code number.

10. AU—assessment-unit name.

11. Data—data sources used to aid in completing the 

data-input form.

12. Comm—primary commodity type in the assessment 

unit, based on the gas-to-oil ratio of the petroleum 

endowment, which includes both the discovered 

and undiscovered petroleum. An assessment unit is 

characterized as being oil prone if the gas-to-oil ratio 

is less than 20,000 cubic feet of gas per barrel of oil; 

otherwise, it is gas prone.

13. Minsize MMB—minimum accumulation size 

considered for assessment, in million barrels of oil 

equivalent (MMBOE).

14. Numoil—number of oil accumulations equal to or 

larger than the minimum accumulation size discovered in the assessment unit.

15. Numgas—number of gas accumulations equal to or 

larger than the minimum accumulation size discovered in the assessment unit.
Tabular Data 17

16. AUM—assessment-unit maturity, the exploration 

maturity of the assessment unit. Assessment-unit 

maturity is classified as “established” if more than 

13 accumulations exceeding minimum size have 

been discovered, “frontier” if 1 to 13 accumulations 

exceeding minimum size have been discovered, or 

“hypothetical” if no accumulations exceeding minimum size have been discovered.

17. MedO1MMB—median size of the set of discovered 

oil accumulations that constitute the first one-third 

or one-half of the total number of oil accumulations 

ranked according to date of discovery within the 

assessment unit, in million barrels of oil (MMBO). 

This size is derived from known oil volumes that 

were adjusted upward to account for estimated future 

reserve growth.

18. MedO2MMB—median size of the set of discovered oil accumulations that constitute the second 

one-third or one-half of the total number of oil 

accumulations ranked according to date of discovery within the assessment unit, in million barrels of 

oil (MMBO). This size is derived from known oil 

volumes that were adjusted upward to account for 

estimated future reserve growth.

19. MedO3MMB—median size of the set of discovered 

oil accumulations that constitute the third one-third 

of the total number of oil accumulations ranked 

according to date of discovery within the assessment 

unit, in million barrels of oil (MMBO). This size is 

derived from known oil volumes that were adjusted 

upward to account for estimated future reserve 

growth.

20. MedG1BCF—median size of the set of discovered 

gas accumulations that constitute the first one-third 

or one-half of the total number of gas accumulations 

ranked according to date of discovery within the 

assessment unit, in billion cubic feet of gas (BCFG). 

This size is derived from known gas volumes that 

were adjusted upward to account for estimated future 

reserve growth.

21. MedG2BCF—median size of the set of discovered gas accumulations that constitute the second 

one-third or one-half of the total number of gas 

accumulations ranked according to date of discovery 

within the assessment unit, in billion cubic feet of 

gas (BCFG). This size is derived from known gas 

volumes that were adjusted upward to account for 

estimated future reserve growth.

22. MedG3BCF—median size of the set of discovered 

gas accumulations that constitute the third one-third 

of the total number of gas accumulations ranked 

according to date of discovery within the assessment 

unit, in billion cubic feet of gas (BCFG). This size is 

derived from known gas volumes that were adjusted 

upward to account for estimated future reserve 

growth.

23. Prob1 %—charge probability, the probability for 

adequate petroleum charge for at least one undiscovered accumulation equal to or larger than the 

minimum accumulation size, somewhere in the 

assessment unit, having the potential to be added to 

reserves. Charge probability is given as a fractional 

value from 0 to 1.0.

24. Prob2 %—rocks probability, the probability for 

adequate reservoirs, traps, and seals for at least one 

undiscovered accumulation equal to or larger than 

the minimum accumulation size, somewhere in the 

assessment unit, having the potential to be added to 

reserves. Rocks probability is given as a fractional 

value from 0 to 1.0.

25. Prob3 %—timing probability, the probability for 

favorable geologic timing for at least one undiscovered accumulation equal to or larger than the 

minimum accumulation size, somewhere in the 

assessment unit, having the potential to be added to 

reserves. Timing probability is given as a fractional 

value from 0 to 1.0.

26. Geoprob %—geologic probability, the product of 

charge, rocks, and timing probabilities. Geologic 

probability is given as a fractional value from 0 to 

1.0.

27. NOmin—estimated minimum (F100) number of 

undiscovered oil accumulations equal to or larger 

than the minimum accumulation size in the assessment unit.

28. NOmod—estimated mode of number of undiscovered oil accumulations equal to or larger than the 

minimum accumulation size in the assessment unit.

29. NOmax—estimated maximum (F0) number of 

undiscovered oil accumulations equal to or larger 

than the minimum accumulation size in the assessment unit.

30. NGmin—estimated minimum (F100) number of 

undiscovered gas accumulations equal to or larger 

than the minimum accumulation size in the assessment unit.

31. NGmod—estimated mode of number of undiscovered gas accumulations equal to or larger than the 

minimum accumulation size in the assessment unit.

32. NGmax—estimated maximum (F0) number of 

undiscovered gas accumulations equal to or larger 

than the minimum accumulation size in the assessment unit.

33. SOminMMB—estimated minimum (F100) size, in 

million barrels of oil (MMBO), of undiscovered oil 

accumulations in the assessment unit.

34. SOmedMMB—estimated median (F50) size, in 

million barrels of oil (MMBO), of undiscovered oil 

accumulations in the assessment unit.
18 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

35. SOmaxMMB—estimated maximum (F0) size, in 

million barrels of oil (MMBO), of undiscovered oil 

accumulations in the assessment unit.

36. SGminBCF—estimated minimum (F100) size, in 

billion cubic feet of gas (BCFG), of undiscovered 

gas accumulations in the assessment unit.

37. SGmedBCF—estimated median (F50) size, in billion cubic feet of gas (BCFG), of undiscovered gas 

accumulations in the assessment unit.

38. SGmaxBCF—estimated maximum (F0) size, in billion cubic feet of gas (BCFG), of undiscovered gas 

accumulations in the assessment unit.

39. GminCF/B—estimated minimum (F100) gas-to-oil 

ratio (GOR), in cubic feet of gas per barrel of oil 

(CFG/BO), of undiscovered oil accumulations equal 

to or larger than the minimum accumulation size in 

the assessment unit.

40. GmodCF/B—estimated mode of gas-to-oil ratio 

(GOR), in cubic feet of gas per barrel of oil (CFG/

BO), of undiscovered oil accumulations equal to or 

larger than the minimum accumulation size in the 

assessment unit.

41. GmaxCF/B—estimated maximum (F0) gas-to-oil 

ratio (GOR), in cubic feet of gas per barrel of oil 

(CFG/BO), of undiscovered oil accumulations equal 

to or larger than the minimum accumulation size in 

the assessment unit.

42. NminB/MMCF—estimated minimum (F100) natural 

gas liquids (NGL) to gas ratio, in barrels of natural 

gas liquids per million cubic feet of gas (BNGL/

MMCFG), of undiscovered oil accumulations equal 

to or larger than the minimum accumulation size in 

the assessment unit.

43. NmodB/MMCF—estimated mode of natural gas 

liquids (NGL) to gas ratio, in barrels of natural 

gas liquids per million cubic feet of gas (BNGL/

MMCFG), of undiscovered oil accumulations equal 

to or larger than the minimum accumulation size in 

the assessment unit.

44. NmaxB/MMCF—estimated maximum (F0) natural 

gas liquids (NGL) to gas ratio, in barrels of natural 

gas liquids per million cubic feet of gas (BNGL/

MMCFG), of undiscovered oil accumulations equal 

to or larger than the minimum accumulation size in 

the assessment unit.

45. LminB/MMCF—estimated minimum (F100) liquids 

(oil plus natural gas liquids) to gas ratio (LGR), in 

barrels of liquids per million cubic feet of gas (BL/

MMCFG), of undiscovered gas accumulations equal 

to or larger than the minimum accumulation size in 

the assessment unit.

46. LmodB/MMCF—estimated mode of liquids (oil plus 

natural gas liquids) to gas ratio (LGR), in barrels of 

liquids per million cubic feet of gas (BL/MMCFG), 

of undiscovered gas accumulations equal to or larger 

than the minimum accumulation size in the assessment unit.

47. LmaxB/MMCF—estimated maximum (F0) liquids 

(oil plus natural gas liquids) to gas ratio (LGR), in 

barrels of liquids per million cubic feet of gas (BL/

MMCFG), of undiscovered gas accumulations equal 

to or larger than the minimum accumulation size in 

the assessment unit.

48. APImin deg—estimated minimum (F100) API gravity, in degrees, of oil in undiscovered oil accumulations in the assessment unit.

49. APImod deg—estimated mode of API gravity, in 

degrees, of oil in undiscovered oil accumulations in 

the assessment unit.

50. APImax deg—estimated maximum (F0) API gravity, 

in degrees, of oil in undiscovered oil accumulations 

in the assessment unit.

51. Smin %—estimated minimum (F100) sulfur content, 

in percent, of oil in undiscovered oil accumulations 

in the assessment unit.

52. Smod %—estimated mode of sulfur content, in percent, of oil in undiscovered oil accumulations in the 

assessment unit.

53. Smax %—estimated maximum (F0) sulfur content, 

in percent, of oil in undiscovered oil accumulations 

in the assessment unit.

54. ODmin m—estimated minimum (F100) drilling 

depth, in meters, of oil in untested cells in oil assessment units.

55. ODf75 m—estimated 75th fractile (F75) of drilling 

depth, in meters, of oil in untested cells in oil assessment units.

56. ODmod m—estimated mode of drilling depth, in 

meters, of oil in untested cells in oil assessment 

units.

57. ODf25 m—estimated 25th fractile (F25) drilling 

depth, in meters, of oil in untested cells in oil assessment units.

58. ODmax m—estimated maximum (F0) drilling depth, 

in meters, of oil in untested cells in oil assessment 

units.

59. OWDmin m—estimated minimum (F100) water 

depth, in meters, of oil in untested cells in oil assessment units (ocean, bays, or lakes; if applicable).

60. OWDmod m—estimated mode of water depth, in 

meters, of oil in untested cells in oil assessment units 

(ocean, bays, or lakes; if applicable).
Tabular Data 19

61. OWDmax m—estimated maximum (F0) water 

depth, in meters, of oil in untested cells in oil assessment units (ocean, bays, or lakes; if applicable).

62. IGmin %—estimated minimum (F100) inert gas 

content, in percent, of gas in untested cells in gas 

assessment units (nitrogen and helium, and so forth).

63. IGmod %—estimated mode of inert gas content, in 

percent, of gas in untested cells in gas assessment 

units (nitrogen and helium, and so forth).

64. IGmax %—estimated maximum (F0) inert gas content, in percent, of gas in untested cells in gas assessment units (nitrogen and helium, and so forth).

65. CO2min %—estimated minimum (F100) carbon 

dioxide content, in percent, of gas in untested cells in 

gas assessment units.

66. CO2mod %—estimated mode of carbon dioxide 

content, in percent, of gas in untested cells in gas 

assessment units.

67. CO2max %—estimated maximum (F0) carbon dioxide content, in percent, of gas in untested cells in gas 

assessment units.

68. H2Smin %—estimated minimum (F100) hydrogen 

sulfide content, in percent, of gas in untested cells in 

gas assessment units.

69. H2Smod %—estimated mode of hydrogen sulfide 

content, in percent, of gas in untested cells in gas 

assessment units.

70. H2Smax %—estimated maximum (F0) hydrogen 

sulfide content, in percent, of gas in untested cells in 

gas assessment units.

71. GDmin m—estimated minimum (F100) drilling 

depth, in meters, of gas in untested cells in gas 

assessment units.

72. GDf25 m—estimated 25th fractile (F25) drilling 

depth, in meters, of gas in untested cells in gas 

assessment units.

73. GDmod m—estimated mode of drilling depth, in 

meters, of gas in untested cells in gas assessment 

units.

74. GDf25 m—estimated 25th fractile (F25) drilling 

depth, in meters, of gas in untested cells in gas 

assessment units.

75. GDmax m—estimated maximum (F0) drilling depth, 

in meters, of gas in untested cells in gas assessment 

units.

76. GWDmin m—estimated minimum (F100) water 

depth, in meters, of gas in untested cells in gas 

assessment units (ocean, bays, or lakes; if applicable).

77. GWDmod m—estimated mode of water depth, in 

meters, of gas in untested cells in gas assessment 

units (ocean, bays, or lakes; if applicable).

78. GWDmax m—estimated maximum (F0) water 

depth, in meters, of gas in untested cells in gas 

assessment units (ocean, bays, or lakes; if applicable).

Data in the kvol####.tab table are derived from a commercially purchased database (NRG Associates, 2007) and are 

current through 2005. This table contains 15 columns. Blank 

cells represent no data. Data columns for these files are as 

follows:

1. Code—assessment-unit code number.

2. Name—assessment-unit name.

3. Numres—number of reported reservoirs in the 

assessment unit.

4. CUMOIL MMB—cumulative production of oil from 

the reported reservoirs in the assessment unit. This 

volume is in million barrels of oil (MMBO).

5. REMOIL MMB—remaining oil reserves in the 

reported reservoirs in the assessment unit. This volume is in million barrels of oil (MMBO).

6. KROIL MMB—known recoverable oil volume 

(cumulative production plus remaining reserves) 

from the reported reservoirs in the assessment unit. 

This volume is in million barrels of oil (MMBO).

7. CUMGAS BCF—cumulative production of natural 

gas from the reported reservoirs in the assessment 

unit. This volume is in billion cubic feet of gas 

(BCFG).

8. REMGAS BCF—remaining natural gas reserves in 

the reported reservoirs in the assessment unit. This 

volume is in billion cubic feet of gas (BCFG).

9. KRGAS BCF—known recoverable natural gas 

volume (cumulative production plus remaining 

reserves) from the reported reservoirs in the assessment unit. This volume is in billion cubic feet of gas 

(BCFG).

10. CUMNGL MMB—cumulative production of natural 

gas liquids (NGL) from the reported reservoirs in the 

assessment unit. This volume is in million barrels of 

natural gas liquids (MMBNGL).

11. REMNGL MMB—remaining natural gas liquids 

(NGL) reserves in the reported reservoirs in the 

assessment unit. This volume is in million barrels of 

natural gas liquids (MMBNGL).

12. KRNGL MMB—known recoverable natural gas 

liquids (NGL) volume (cumulative production plus 

remaining reserves) from the reported reservoirs in 

the assessment unit. This volume is in million barrels 

of natural gas liquids (MMBNGL).
20 Tabular Data and Graphical Images in Support of the U.S. Geological Survey National Oil and Gas Assessment

13. CUMPET MMB—cumulative production of 

petroleum (oil, gas, and NGL) from the reported 

reservoirs in the assessment unit. This volume is in 

million barrels of oil equivalent (MMBOE).

14. REMPET MMB—remaining petroleum (oil, gas, 

and NGL) reserves in the reported reservoirs in the 

assessment unit. This volume is in million barrels of 

oil equivalent (MMBOE).

15. KRPET MMB—known recoverable petroleum (oil, 

gas, and NGL) volume (cumulative production plus 

remaining reserves) from the reported reservoirs in 

the assessment unit. This volume is in million barrels 

of oil equivalent (MMBOE).

References Cited

Cardinal, D.F., Miller, T., Stewart, W.W., and Trotter, J.F., eds, 

1989, Wyoming oil and gas fields symposium Bighorn and 

Wind River Basins: Wyoming Geological Association, 

555 p. 

IHS Energy Group, 2007a [includes data current as of December 2007], PI/Dwights Plus US production data: IHS 

Energy Group; database available from IHS Energy Group, 

15 Inverness Way East, D205, Englewood, CO 80112, 

U.S.A.

IHS Energy Group, 2007b [includes data current as of December 2007], PI/Dwights Plus US well data: IHS Energy 

Group; database available from IHS Energy Group, 15 

Inverness Way East, D205, Englewood, CO 80112, U.S.A.

NRG Associates, 2007 [includes data current as of December 2005], The significant oil and gas fields of the United 

States: NRG Associates, Inc.; database available from NRG 

Associates, Inc., P.O. Box 1655, Colorado Springs, CO 

80901, U.S.A.

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