Link to USGS home page.
Open-File Series 03-037: 508 Document

 

The New Albany Shale Petroleum System, Illinois Basin - Data and Map

Image Archive from the Material-Balance Assessment

 

D.K. Higley, M.E. Henry, M.D. Lewan, and J.K. Pitman

 

2003

 . .

 

This report is preliminary and has not been reviewed for conformity

with U.S. Geological Survey editorial standards or with the North

American Stratigraphic Code. 

 

Any use of trade, firm, or product names is for descriptive purposes

only and does not imply endorsement by the U.S. Government

 

Open-File Report 2003-03-037

 

U.S. Department of the Interior

U.S. Geological Survey

 

++++++++++++++++++++++++++++++++++++++++++++++

 

U.S. Department of the Interior

U.S. Geological Survey Open-File 03-037

 

THE NEW ALBANY SHALE PETROLEUM SYSTEM, ILLINOIS BASIN - DATA AND MAP

IMAGE ARCHIVE FROM THE MATERIAL-BALANCE ASSESSMENT

 

D.K. Higley, M.E. Henry, M.D. Lewan, and J.K. Pitman

 

TABLE OF CONTENTS

 

README FILE   

DATA FILES README AND EXAMPLES

ABSTRACT

INTRODUCTION

DISTRIBUTION OF OIL, GAS, AND NON-PRODUCTIVE WELLS

* Petroleum Production in the Basin

* Distribution of Oil, Gas, and Non-productive Wells

METHODS AND RESULTS

* Source-Rock Characterization

* Estimated Amounts of Generated and Produced Oil, Known Petroleum

Volume of Oil, and Original-Oil-In-Place

* Estimates of Losses from Carrier Beds

* Factors That Influence/Control Estimation Of Hydrocarbon Resources

CONCLUSIONS

SELECTED REFERENCES

ACKNOWLEDGEMENTS

GLOSSARY

 

APPENDICES

 

* Appendix 1, A database that contains median porosity and permeability

information from core samples (Appendix 1, located in data/

fileform/porperm.xls) that was created from analyses supplied by the

Illinois State and Indiana Geological Surveys. File names are

porperm.xls, porperm.csv, and porperm.prn.

 

* Appendix 2.  Maps in this report are based primarily on results from

Rock-Eval pyrolysis of 475 samples from 262 locations across the

Illinois Basin. Multiple samples from the same location were averaged.

Data files that list HI, TOC, well location, and other information are

located in the data subdirectory. The files are stored in Microsoft

EXCEL (HI_TOC.xls), comma-delimited (HI_TOC.csv), and space-delimited

(HI_TOC.prn) formats.  Fileform.htm contains an example and explanation

of data and methods.

 

LIST OF FIGURES  

 

Figure 1. Index map of major structural features in the eastern mid-

continent of the United States (Modified from Buschbach and Kolata,

1991, reprinted by permission of the American Association of Petroleum

Geologists and AAPG Data Systems (Datapages, Inc.), whose permission is

required for further use). Green dashed line is generalized outline of

the Illinois Basin. The large 31 KB image is named indexmp.jpg .

 

Figure 2. Major structural features of the Illinois Basin and bounding

areas. Shown are major fault systems, anticlines, synclines,

monoclines, and crypto explosive or impact structures in the region

(modified from Buschbach and Kolata, 1991; Treworgy, 1981, reprinted by

permission of The American Association of Petroleum Geologists and AAPG

Data Systems (Datapages, Inc.), whose permission is required for

further use). The large 90KB image is named bstruct.jpg .

 

Figure 3. Chart showing times of structural activity in the Illinois

Basin area. Illustrated are major structural events in the region and

plate tectonic movement across the world. These are plotted on a

numerical time scale from the COSUNA chart that was modified by Shaver

and others (1985). Diagram is modified from Kolata and Nelson (1991,

reprinted by permission of The American Association of Petroleum

Geologists and AAPG Data Systems (Datapages, Inc.), whose permission is

required for further use). The large 30 KB image is named agestru.jpg .

 

Figure 4. Distribution of oil and gas wells from Silurian- through

Pennsylvanian- age reservoirs in the Illinois Basin; approximate basin

outline is marked by a thick orange line. The thin red line shows

region of thermally mature source rocks. Major structural features are

labeled; fault names are black text while blue text marks arches,

monoclines, synclines, and domes. Catchment 1 is labeled and catchments

2 through 7 are located clockwise and sequentially from 1. Faint purple

lines segregate each catchment.  The irregular blue line outlines

maximum subsurface and surface extent of Chesterian-age formations. The

large 151 KB image is named oilstruc.jpg . The small-scale image

without the labeled structures is named allprod.jpg .

 

Figure 5. Decreasing hydrogen index (HI) contours show regions of

increasing thermal maturity of New Albany Shale source rocks within the

Illinois Basin. Contour interval is 50 HI. The 400 HI contour (red

line) outlines the area of source rocks that are thermally mature for

oil generation. Catchments are labeled clockwise from 1 to 7. Irregular

dark-green line outlines the maximum extent of the New Albany Shale

(modified from Lewan and others, 1995, 2002). Large scale 112 KB image

is named contorhi.jpg .

 

Figure 6 a through g. Below are a series of 3-D images of hydrogen

indices (HI) values cut by structure on the top of the New Albany

Shale. HI contours show location of the generative basin as outlined by

a HI of 400. Major fault traces are shown in red on some views.

Vertical displacement by the faults is illustrated in shades of gray.

Vertical exaggeration is 20 times. "LS" marks the La Salle anticlinal

belt and "RC" labels the Rough Creek fault zone on some images.

Included are north arrows and azimuth relative to north (degrees), and

inclination relative to a horizontal plane (degrees). Small-size images

are 28 to 53 KB, and the enlarged images are 91 to 224 KB.

 

Figure 7. Generalized stratigraphic column of Devonian and

Mississippian strata in the southern part of the Illinois Basin.

Horizontal red lines to the right of the column indicate the primary

oil and gas productive intervals. Shown are names and vertical and

lateral associations of strata from Late Devonian to Late Mississippian

time. The New Albany Shale hydrocarbon source rock is also labeled

(Modified from Bell and others, 1961; Buschbach and Kolata, 1991,

reprinted by permission of The American Association of Petroleum

Geologists and AAPG Data Systems (Datapages, Inc.), whose permission is

required for further use). The large 19 KB image is named stratsec.jpg.

 

Figure 8. This generalized southwest-northeast stratigraphic cross

section of the Middle Devonian through Mississippian Kaskaskia sequence

shows vertical and lateral extent of primary hydrocarbon source rock

and reservoir rocks in the Illinois Basin (modified from Treworgy and

Devera, 1991, reprinted by permission of The American Association of

Petroleum Geologists and AAPG Data Systems (Datapages, Inc.), whose

permission is required for further use). This is a 20 KB image named

devmisxs.jpg .

 

Figure 9. Distribution of more than 4,700 wells with petroleum

production from Pennsylvanian-age reservoirs in the Illinois Basin.

Catchment 1 is labeled and catchments 2 through 7 are located clockwise

and sequentially from 1. Purple lines segregate each catchment.  An

irregular dark-reddish-brown line outlines the maximum extent of

Pennsylvanian-age formations. Well location data were derived from

PI/Dwights Well History Control System database (1996).  The large 104

KB image is named pennprod.jpg.

 

Figure 10. Shown are greater than 2,000 dry holes that reach total

depth within Pennsylvanian-age formations. Catchment 1 is labeled and

catchments 2 through 7 are located clockwise and sequentially from 1.

Purple lines segregate each catchment.  An irregular dark-reddish-brown

line outlines the maximum extent of Pennsylvanian-age formations. Well

location data were derived from PI/Dwights Well History Control System

database (1996).  The large 104KB image is called penndry.jpg.

 

Figure 11. Shown are more than 38,000 dry holes that reach total depth

within Mississippian-age or older formations. Catchment 1 is labeled

and catchments 2 through 7 are located clockwise and sequentially from

1. Purple lines segregate each catchment.  Subsurface or surface extent

of Chesterian-age formations is outlined by the irregular blue line.

Well location data were derived from PI/Dwights Well History Control

System database (1996).  The large 104KB image is called missdry.jpg .

 

Figure 12. Chesterian regressive depositional cycle is modified from

Pryor and others (1991, reprinted by permission of The American

Association of Petroleum Geologists and AAPG Data Systems (Datapages,

Inc.), whose permission is required for further use). Shown are

spontaneous potential (SP) and resistivity well-log signatures,

lithology, and depositional systems for an idealized shoaling-upward

regressive system; most cycles are bounded by disconformities (shown by

wavy horizontal lines). The large 16 KB image is named chesdep.jpg.

 

Figure 13. This Valmeyeran regressive depositional cycle is modified

from Pryor and others (1991, reprinted by permission of The American

Association of Petroleum Geologists and AAPG Data Systems (Datapages,

Inc.), whose permission is required for further use). Shown are

spontaneous potential (SP) and resistivity well-log signatures,

lithology, and depositional systems for an idealized upward-shoaling

regressive carbonate cycle. The large 36 KB image is named valmdep.jpg.

 

Figure 14. Distribution of petroleum production from Chesterian-age

reservoirs in the Illinois Basin. Shown are more than 13,000 oil and

600 gas wells. Catchment 1 is labeled and catchments 2 through 7 are

located clockwise and sequentially from 1. Purple lines segregate each

catchment.  The irregular blue line outlines the maximum extent of

Chesterian-age formations. Well location data were derived from

PI/Dwights Well History Control System database (1996).  The large 112

KB image is named chesprod.jpg.

 

Figure 15.  This map shows wells that produce from units within the

Mississippian Valmeyeran Series. The catchments 1 through 7 are

labeled. Purple lines segregate each catchment.  The irregular dark-

green line outlines the maximum extent of Valmeyeran-age formations. 

Primary producing formations are Ste. Genevieve, Salem, and Aux Vases.

There are more than 12,000 oil wells (green) and 400 gas wells (red).

Well location data were derived from PI/Dwights Well History Control

System database (1996).  The large 107KB image is named valmprod.jpg .

 

Figure 16. Distribution of oil and gas wells from Silurian- and

Devonian-age formations. Shown are more than 2,700 oil and 100 gas

wells. Catchment 1 is labeled and catchments 2 through 7 are located

clockwise and sequentially from 1. Purple lines segregate each

catchment.  Well location data were derived from PI/Dwights Well

History Control System database (1996).  The large 93KB image is named

sildprod.jpg.

 

Figure 17. Thickness of source-rock-quality New Albany Shale across the

generative basin, Illinois Basin. Isopach interval is 20 ft (6 m).

Greatest thickness of source rocks is the red "bulls eye" located near

the intersection of Illinois, Indiana, and Kentucky. This area is east

of the basin axis, and directly east of the "bulls eye" of greatest

maturation level. Catchment 1 is labeled and catchments 2 through 7 are

located clockwise and sequentially from 1. Purple lines segregate each

catchment.  Maximum extent of the New Albany Shale is shown by the dark

green line (modified from Lewan and others, 1995). Large-scale 122 KB

image is named srthick.jpg.

 

Figure 18. Isopach map of the Selmier Member of the New Albany Shale.

Contour interval is 10 ft. (3.0 m). Catchment 1 is labeled and

catchments 2 through 7 are located clockwise and sequentially from 1.

Purple lines segregate each catchment.  Maximum extent of the New

Albany Shale is shown by the dark green line (modified from Lewan and

others, 1995). The large 141 KB image is named selmiso.jpg.

 

Figure 19. Percent thickness of the Selmier Member of the New Albany

Shale that exhibits gamma signatures of 120 API units or greater.

Contour interval is 20%. Red line outlines the generative basin.

Catchment 1 is labeled and catchments 2 through 7 are located clockwise

and sequentially from 1. Purple lines segregate each catchment.  Basin

axis is the purple line that separates catchments a) 2 and 7, b) 3 and

6, and c) 4 and 5. Greatest percentage of source-rock quality shales

(thickest intervals of high gamma signature) are along the basin axis.

Maximum extent of the New Albany Shale is the dark green line (modified

from Lewan and others, 1995).  Sample locations are small inverted

triangles. These are more readily viewed on the large 131 KB

selmhga.jpg image.

 

TABLES

 

Table 1. Estimated amounts of hydrocarbons that have been generated and

produced from the New Albany Shale petroleum system in the Illinois

Basin. Shown are estimated volumes of hydrocarbons both within the area

of mature source rocks and outside this boundary. The thermally mature

region is defined by a hydrogen index (HI) value of 400. Included are

estimates of cumulative production and known petroleum volume of oil,

and original-oil-in-place (OOIP).  The known petroleum volume of oil is

36.22% of the OOIP of 11.45 BBO (billion barrels of oil). [If your view

does not read the HTML v. 3 format, the file is also saved as comma-

delimited ( ooipnum.csv), text ( ooipnum.txt), and EXCEL v 4.0 (

ooipnum.xls) formats.]

 

Table 2. Catchment number (CN), cumulative production (CUM) and known

petroleum volume of oil (K VOL), and original oil in place (OOIP)

values for the New Albany Shale petroleum system.  Volumes are millions

of barrels of oil (MMBO).  "Within" and "outside" refer to location of

produced, in-place, and (or) recoverable oil within or outside the 400

HI contour that encloses thermally mature source rocks.  The final

column shows the percent of oil production within the hydrocarbon

generative area of the Illinois Basin. [If your Web browser cannot view

the below table, it is also saved as comma-delimited ( oilprod.csv) and

Microsoft EXCEL v. 5.0 ( oilprod.xls) files. The external HTML table is

named oilprod.htm .]

 

ABSTRACT

 

The data files and explanations presented in this report were used to

generate published material-balance approach estimates of amounts of

petroleum 1) expelled from a source rock, and the sum of 2) petroleum

discovered in-place plus that lost due to 3) secondary migration

within, or leakage or erosion from a petroleum system. This study

includes assessment of cumulative production, known petroleum volume,

and original oil in place for hydrocarbons that were generated from the

New Albany Shale source rocks.  More than 4.00 billion barrels of oil

(BBO) have been produced from Pennsylvanian-, Mississippian-, Devonian-

, and Silurian-age reservoirs in the New Albany Shale petroleum system.

Known petroleum volume is 4.16 BBO; the average recovery factor is

103.9% of the current cumulative production. Known petroleum volume of

oil is 36.22% of the total original oil in place of 11.45 BBO. More

than 140.4 BBO have been generated from the Upper Devonian and Lower

Mississippian New Albany Shale in the Illinois Basin. Approximately

86.29 billion barrels of oil that was trapped south of the Cottage

Grove fault system were lost by erosion of reservoir intervals. The

remaining 54.15 BBO are 21% of the hydrocarbons that were generated in

the basin and are accounted for using production data. 

Included in this publication are 2D maps that show the distribution of

production for different formations versus the Rock-Eval pyrolysis

hydrogen-indices (HI) contours, and 3D images that show the close

association between burial depth and HI values.  The primary vertical

migration pathway of oil and gas was through faults and fractures into

overlying reservoir strata. About 66% of the produced oil is located

within the generative basin, which is outlined by an HI contour of 400.

The remaining production is concentrated within 30 miles (50 km)

outside the 400 HI contour. The generative basin is subdivided by

contours of progressively lower hydrogen indices that represent

increased levels of thermal maturity and generative capacity of New

Albany Shale source rocks. The generative basin was also divided into

seven oil-migration catchments. The catchments were determined using a

surface-flow hydrologic model with contoured HI values as input to the

model.

 

INTRODUCTION

 

In the 1990's the material-balance approach to assessing petroleum

resources was tested with a study of the New Albany Shale petroleum

system in the Illinois Basin.  An initial publication entitled

"Feasibility Study of Material-Balance Assessment of Petroleum from the

New Albany Shale in the Illinois Basin" by Lewan and others, USGS

Bulletin 2137, 1995, indicated that this was a promising method of

assessing oil and gas resources, and outlined the methodology.  A

second, "Material-balance assessment of the New Albany Shale-Chesterian

petroleum system of the Illinois Basin" by Lewan and others, 2002, was

published in the AAPG bulletin series and details the geology, methods

of geochemical analysis, and results of the study.  This open file

report details the evaluation of the distribution and volumes of

produced oil and gas, and includes maps and raw geochemical and other

data that were used to generate but were not included in previous

papers.  The New Albany is assigned group rank in Illinois; in Indiana

and western Kentucky the New Albany is a formation-rank unit.  In this

report, the name "New Albany Shale" will be used throughout the

Illinois Basin.  Highlighted text and graphics are links to figures and

large-size images in which the sizes are approximately 16 by 16 inches

and scales are 1:1,000,000.  They may also be links to the glossary;

most of the definitions are derived from the Dictionary of Geological

Terms, 1984, Higley and others, 1997, and Klett and others, 2000.

 

The Illinois Basin is located in southwestern Indiana, western

Kentucky, and all but northernmost Illinois. Major structural features

in the basin and bounding areas are shown on figures 1 and 2. Times of

structural activity are illustrated on figure 3. Petroleum production

is concentrated along many of the major faults and other structures.

About 42% of the almost 90,000 holes drilled are oil and (or) gas

productive. Mississippian reservoirs provide 70% of the producing wells

in the basin, which are equally split between Chesterian- and

Valmeyeran-age formations. Approximately 60% of oil produced from the

basin is from Chesterian reservoirs (Howard, 1991). Additional

production is primarily from Valmeyeran (greater than 20%),

Pennsylvanian (13%), and Silurian and Devonian (7%) reservoirs (Howard,

1991). A simplifying aspect of the New Albany Shale petroleum system is

that almost all reported production is oil. Average gas to oil ratio

for the Mississippian and Pennsylvanian producing formations is 750

cubic feet of gas per barrel (CFG/BBL) (Macke, 1996).

 

About 66% of the produced oil occurs within the area of thermally-

mature New Albany Shale source rocks, which suggests the primary

hydrocarbon migration direction was upwards through faults and

fractures into overlying reservoir strata. Geochemical analyses of oil-

field brines across the Illinois Basin indicate short migration

distances (Abrams 1995) for these hydrocarbons that are probably

sourced from the New Albany Shale; brines typically exhibit ionic

composition of the (probable in-situ) seawater with ionic

concentrations of as much as 5 times seawater. Long-range migration of

formation fluids generally dilutes connate water. Abrams further

postulates that density drive due to buoyancy was the primary mechanism

of oil migration. The influence of lateral migration through porous

carrier beds may be important in large oil fields such as Louden and

Main Consolidated that lie near or outside the limit of mature source

rocks in the Illinois Basin. The Fairfield Subbasin (Figure 1), within

the Illinois Basin, contains most of the oil produced in the New Albany

Shale petroleum system. Bordering the Fairfield Subbasin are the

primary barriers and conduits to lateral migration of hydrocarbons

(Figure 2); structures listed below also define some of the boundaries

of catchments in the basin that influence hydrocarbon migration

pathways and traps.

 

1. The Rough Creek -Shawneetown fault system, near the southern

boundary of the basin, is the northern boundary of the Rough Creek

graben. This east-west trending fault system is a probable barrier to

migration of hydrocarbons and is located just east of the Cottage Grove

fault system. 

 

2. The Cottage Grove fault system is a series of right-lateral wrench

faults (Nelson and Lumm, 1985) that mark the southern limit of

significant oil and gas production in the western half of the basin.

Approximately 98% of reported oil and gas production is located north

of this fault system, based on analysis of production data from Nehring

(1996), and PI/Dwights Production Data on CD-ROM (1996).

 

3. The La Salle anticlinal belt is a primary barrier to eastward

migration of hydrocarbons. This belt forms the northeast boundary of 

the Fairfield Subbasin and consists of sub-parallel north-south

trending anticlines.

 

4. The Wabash Valley fault system is located south of the La Salle

anticlinal belt, along the Illinois/Indiana state line. This system was

an important vertical and north-south oil migration corridor.

Hydrocarbons accumulated in reservoir rocks adjacent to or between

faults, and in upthrown blocks. In Indiana, oil commonly occurs within

the fault system.   Figure 4 and the detailed allprod.jpg map show oil

and gas wells near this and the other structural features that outline

the hydrocarbon generative area of the basin.

 

5. Westward migration of hydrocarbons was slowed by the Louden and

Salem anticlines and by the Du Quoin monocline. This monocline dips

steeply to the east and forms the western edge of the Fairfield

Subbasin. The faulted monocline near the western terminus of the

Cottage Grove system appears to have focused oil migration northward.

The two largest fields in the basin are located on the Salem and Louden

anticlines, which are north of and approximately on strike with the Du

Quoin monocline. Seismic data revealed that the Louden anticline is

faulted on both flanks and that these faults may extend to the basement

(Nelson, 1991). Only minor amounts of oil exist in Mississippian

reservoirs west of the monocline suggesting that faults and other

structural features served as barriers to westward migration.

 

 

Figure 1. Index map of major structural features in the eastern mid-

continent of the United States (Modified from Buschbach and Kolata,

1991, reprinted by permission of the American Association of Petroleum

Geologists and AAPG Data Systems (Datapages, Inc.), whose permission is

required for further use). Green dashed line is generalized outline of

the Illinois Basin. The large 31 KB image is named indexmp.jpg .

 

 

Figure 2. Major structural features of the Illinois Basin and bounding

areas. Shown are major fault systems, anticlines, synclines,

monoclines, and crypto explosive or impact structures in the region

(modified from Buschbach and Kolata, 1991; Treworgy, 1981, reprinted by

permission of The American Association of Petroleum Geologists and AAPG

Data Systems (Datapages, Inc.), whose permission is required for

further use). The large 90KB image is named bstruct.jpg .

 

 

Figure 3. Chart showing times of structural activity in the Illinois

Basin area. Illustrated are major structural events in the region and

plate tectonic movement across the world. These are plotted on a

numerical time scale from the COSUNA chart that was modified by Shaver

and others (1985). Diagram is modified from Kolata and Nelson (1991,

reprinted by permission of The American Association of Petroleum

Geologists and AAPG Data Systems (Datapages, Inc.), whose permission is

required for further use). The large 30 KB image is named agestru.jpg .

 

 

Figure 4. Distribution of oil and gas wells from Silurian- through

Pennsylvanian- age reservoirs in the Illinois Basin; approximate basin

outline is marked by a thick orange line. The thin red line shows

region of thermally mature source rocks. Major structural features are

labeled; fault names are black text while blue text marks arches,

monoclines, synclines, and domes. Catchment 1 is labeled and catchments

2 through 7 are located clockwise and sequentially from 1. Faint purple

lines segregate each catchment.  The irregular blue line outlines

maximum subsurface and surface extent of Chesterian-age formations. The

large 151 KB image is named oilstruc.jpg . The small-scale image

without the labeled structures is named allprod.jpg .

 

The New Albany Shale was deposited as brownish-black laminated shales

in a marine, stratified anoxic basin; primary environments were

transitional shelf, slope, and basin (Cluff and others, 1981). Time

span of New Albany Shale deposition to possible completion of

hydrocarbon migration is Late Devonian through Late Jurassic, about 225

m.y. Hydrocarbon expulsion in southern Illinois began during the Middle

Pennsylvanian and reached its peak in Late Pennsylvanian to Early

Permian time (Cluff and Byrnes, 1991). Extensive folding and faulting

coincident with this event created many of the major structural traps

in the basin (Figure 3).  A late stage of hydrocarbon migration

probably occurred during tectonic activity after maximum burial depth

(post-Early Permian) (Figure 3) (Lewan and others, 2002); however this

was minimal as indicated by the fact that about 66% of petroleum

production is from within the generative basin, and only 2% of

hydrocarbon production is from south of the Cottage Grove and Rough

Creek-Shawneetown fault systems.

 

Bethke and others (1991) state that migration of hydrocarbons into

traps began during Early Cretaceous time (100 Ma).  Bethke and others

(1991) suggest that long-range, northward, migration of hydrocarbons

(100 km (62 mi.) or more) resulted from uplift during Mesozoic time of

the Pascola Arch, located along the southern boundary of the Illinois

Basin. They further postulate that oil generated from the Devonian and

Mississippian New Albany Shale migrated through underlying Devonian and

Silurian carbonates along a karstified surface of a regional

unconformity. They doubt the oil migrated over long distances along

faults; they indicate the central basin contains few fault systems, and

none are believed oriented along their inferred migration routes.

Primary migration mechanisms were attributed to hydrodynamic flow and

buoyancy. Fluid expulsion is also associated with sediment compaction.

 

Emplacement of hydrocarbons was influenced by their vertical migration

along fault systems, combined with potential sealing effects of some

faults and associated structures. Results of this migration include

vertical expansion of the petroleum system into overlying younger

formations, and limiting the lateral migration and extent of oil and

gas by sealing faults and low-permeability formations. Erosional

removal of potential reservoir units was particularly widespread south

of the Cottage Grove fault system (Figure 4). During this time an

estimated 1-3 km (0.6 to 2 mi.) of section in southern Illinois was

removed (Cluff and Byrnes, 1991; Damberger, 1971). This was determined

based on extrapolation of trends in thicknesses of Paleozoic strata

across the basin, and by anomalous values of thermal maturity in near-

surface coal beds.

 

The New Albany Shale petroleum system was divided into seven migration

drainage areas, or catchments. Petroleum charge, losses, and in-place

resources were evaluated separately for each catchment, both within and

outside the generative basin. Catchments and hydrocarbon migration

pathways were determined using surface hydrologic modeling utilities in

the Arc/Info geographic information systems (GIS) software mapping

program (Environmental System Research Institute, Inc., 1997). Because

decrease in hydrogen index (HI) values is associated with an increase

in thermal maturity, the HI contour map resembles a depression. In

order to model movement of hydrocarbons under buoyant forces by using

hydrologic flow modeling software, the model must be inverted. The HI

values for each of the 262 locations were multiplied by minus one.

These negative HI values were then used as input to the watershed

modeling utility in the Arc/Info program. Regions of source rocks that

are thermally mature for oil generation are defined by a 400 HI contour

(Figure 5); this is also the limiting polygon for calculation of

amounts of generated hydrocarbons. HI values within the thermally

mature portion of the basin range from 10 to 400 mg/g TOC (Appendix 2,

HI_TOC.xls).  The study area was initially divided into 21 drainage

regions, or catchments. These were condensed into seven catchments by

combining drainage areas that had ambiguous boundaries. Petroleum

production data was calculated using these 21 catchments, and the data

were merged into the final 7 catchments. Boundaries between catchments

were extended to the New Albany Shale subcrop/outcrop by drawing

perpendicular lines outward from the 400 HI contour.

The 400 HI contour generally follows the structure of the Fairfield

Subbasin. The 100 HI contour outlines an area of higher thermal

maturity in southern Illinois.  Maximum lateral movement along the

Cottage Grove fault systems is less than one mile (Nelson and Krausse,

1981) and is not associated with noticeable displacement of HI

contours.

 

The regions of the Illinois Basin that are thermally mature for oil and

gas that was sourced from the New Albany Shale are shown on figures 5

and 6 a-g. Figures 6a through 6g are 3-D images of hydrogen indices

contoured across the basin; these HI contours are draped on the top of

the New Albany Shale to better show the association between HI and the

basin structure. Surfaces are offset by movement along major fault

systems. Maps are based primarily on results from Rock-Eval pyrolysis

of 475 samples from 262 locations across the Illinois Basin. Multiple

samples from the same location were averaged. The thermally mature area

includes the Fairfield Subbasin (400 HI red contour) (Figure 4).

Contoured values greater than 400 HI are not displayed; these areas are

thermally immature for oil generation. Data files that list HI, TOC,

well location, and other information are located in the data

subdirectory. The files are stored in Microsoft EXCEL ( HI_TOC.xls),

comma-delimited ( HI_TOC.csv), and space-delimited (HI_TOC.prn, .txt)

formats.  Fileform.htm contains an example and explanation of data and

methods.

 

The following are factors that influenced the generation and migration

of hydrocarbons from the New Albany Shale and were used in our

analyses:

1. Thermal maturity is primarily a measure of burial depth at the time

of hydrocarbon generation and expulsion.

 

2. Petroleum migrates vertically under buoyant forces. Permeability

barriers mainly deflect the movement laterally, but in an up-dip

direction.

 

3. General features of petroleum migration were modeled using a

structure contour map of elevation of the top of the New Albany Shale.

This structure was used as input to a hydrologic flow modeling computer

program that was modified to account for flow behavior of hydrocarbons.

 

4. The basin configuration is such that impermeable layers that are

encountered by migrating hydrocarbons will have similar geometry to the

top of the New Albany Shale.

 

5. Existing pathways, such as faults and fractures, allowed for mostly

vertical migration of hydrocarbons from the New Albany Shale into

overlying porous and permeable reservoirs. Vertical barriers were

hundreds of feet of generally dense limestone and lesser amounts of

shales of the Chesterian and Valmeyeran Series (Figures 7, 8).

 

Vertical relationship of New Albany Shale to primary reservoir

intervals is shown on the stratigraphic column of Devonian and

Mississippian strata in the southern part of the Illinois Basin (Figure

7). Formations that are oil productive are marked by horizontal red

lines.  Figure 8 is a generalized stratigraphic cross section of this

time interval. Also shown is the extent of Chesterian and Valmeyeran

Series across the basin. Regressive depositional cycles for the

Chesterian and Valmeyeran Series were tied to well-log signatures and

lithologic descriptions (Treworgy and Devera, 1991).

 

 

 Figure 5. Decreasing hydrogen index (HI) contours show regions of

increasing thermal maturity of New Albany Shale source rocks within the

Illinois Basin. Contour interval is 50 HI. The 400 HI contour (red

line) outlines the area of source rocks that are thermally mature for

oil generation. Catchments are labeled clockwise from 1 to 7. Irregular

dark-green line outlines the maximum extent of the New Albany Shale

(modified from Lewan and others, 1995, 2002). Large scale 112 KB image

is named contorhi.jpg .

 

Figure 6 a through g. Below are a series of 3-D images of hydrogen

indices (HI) values cut by structure on the top of the New Albany

Shale. HI contours show location of the generative basin as outlined by

a HI of 400. Major fault traces are shown in red on some views.

Vertical displacement by the faults is illustrated in shades of gray.

Vertical exaggeration is 20 times. "LS" marks the La Salle anticlinal

belt and "RC" labels the Rough Creek fault zone on some images.

Included are north arrows and azimuth relative to north (degrees), and

inclination relative to a horizontal plane (degrees). Small-size images

are 28 to 53 KB, and the enlarged images are 91 to 224 KB.

 

Figure 6a.  nalb115.jpg

Figure 6b.  nalb111.jpg

Figure 6c.  nalb110.jpg

Figure 6d.  nalb112.jpg

Figure 6e.  nalb116.jpg

Figure 6f.  nalb114.jpg

Figure 6g.  nalb113.jpg

 

 

Figure 7. Generalized stratigraphic column of Devonian and

Mississippian strata in the southern part of the Illinois Basin.

Horizontal red lines to the right of the column indicate the primary

oil and gas productive intervals. Shown are names and vertical and

lateral associations of strata from Late Devonian to Late Mississippian

time. The New Albany Shale hydrocarbon source rock is also labeled

(Modified from Bell and others, 1961; Buschbach and Kolata, 1991,

reprinted by permission of The American Association of Petroleum

Geologists and AAPG Data Systems (Datapages, Inc.), whose permission is

required for further use). The large 19 KB image is named stratsec.jpg.

 

 

Figure 8. This generalized southwest-northeast stratigraphic cross

section of the Middle Devonian through Mississippian Kaskaskia sequence

shows vertical and lateral extent of primary hydrocarbon source rock

and reservoir rocks in the Illinois Basin (modified from Treworgy and

Devera, 1991, reprinted by permission of The American Association of

Petroleum Geologists and AAPG Data Systems (Datapages, Inc.), whose

permission is required for further use). This is a 20 KB image named

devmisxs.jpg .

 

DISTRIBUTION OF OIL, GAS, AND NON-PRODUCTIVE WELLS

 

Petroleum Production in the Basin

 

The Clark County Division field was drilled in the Illinois Basin in

1900; this is the first field that contains discovery date information

for the PI/Dwights WHCS (1996) and Production Data on CD-ROM (1999) and

Nehring databases (1996).  Average discovery date is 1946 for 320

fields in the databases that contain this information. The Illinois

Basin has a mature exploration status. Macke (1996) estimated that 10

or fewer oil accumulations of 1 million barrels or greater remain to be

discovered in Mississippian and Pennsylvanian formations in the basin

and that remaining reserve growth will mainly result from secondary and

tertiary methods of petroleum production from existing fields.  The

basin contains more than sixty different petroleum pay intervals that

range in age from Ordovician to Pennsylvanian; production is primarily

from structural traps at depths of less than 5,500 ft (1,675 m) (Howard

and Whitaker, 1990). "A number of hydrocarbon occurrences are closely

related to the tops of three major carbonate intervals"; these are

listed by Howard (1991) as being the Upper Ordovician Ottowa

Supergroup, the Silurian and Devonian Hunton Supergroup, and the

Mississippian Valmeyeran Series. Most hydrocarbon production in the

basin has been from siliciclastic intervals in Chesterian and

Pennsylvanian rocks (Howard, 1991). Oltz and others (1991) determined

that the Illinois Basin has almost 1,700 fields; these produce mainly

oil from about 7,000 separate sandstone and carbonate reservoirs.

Ninety-six percent of this production is stripper, or less than 10

BO/day per well; this percentage is six times greater than the national

average for stripper production (Oltz and others, 1991). Organic

geochemical correlations indicate that more than 99% of discovered

petroleum in the basin was derived from the New Albany Shale (Hatch and

others, 1991).

 

Almost 90,000 wells have been drilled in the Illinois Basin; 42%, or

about 38,000 wells, are currently listed as oil and (or) gas productive

(PI/Dwights WHCS data through Dec, 1996). Total number of dry holes

across the basin is 47,800 (PI/Dwights WHCS database through 1996). 

Figure 4 shows distribution of oil and gas wells across the basin.

Production is from Silurian-through Pennsylvanian-age reservoirs.

 

Distribution of Oil, Gas, and Non-Productive Wells

 

The following maps show areal distribution of oil and gas wells and dry

holes (non-productive wells) in the Illinois Basin. The primary source

of well data for the well distribution figures is the PI/Dwights Well

History Control System data through 1996. The smooth solid red line on

figures is the 400 HI contour; this outlines the hydrocarbon generative

area of the New Albany Shale as defined by a hydrocarbon index value of

400. Purple lines within the generative basin segment the seven

catchments; perpendiculars are extended to the boundaries of the

formation or basin. Labeled outcrop/subcrop extents are generalized in

areas, particularly south of the Rough Creek and Cottage Grove fault

systems and along the southwestern border of the basin.

 

Numerous wells produce from several different age and (or) formation

intervals and production is commingled; allocation of percentages of

total production can therefore be somewhat misleading. This can result

in over- or under-reporting of production data. Production from

Pennsylvanian-age formations is illustrated on figure 9.  Approximately

13% of basin production is from Pennsylvanian-age reservoirs according

to Howard (1991).  More than 4,700 mostly oil wells produce from

Pennsylvanian formations; this is 7.8% of total oil and gas wells in

the basin (PI/Dwights WHCS data, 1996).  Seventy-five percent of

Pennsylvanian production is concentrated along the north-south trending

La Salle anticlinal belt (Swann and Bell, 1958).  The largest field is

Main Consolidated, which is the large crescent-shaped field that

overlies the anticlinal belt and the 400 HI contour in catchment 2

(fig. 9).  Dry hole maps are useful to show the concentration of

drilling across the basin.  2,000 dry holes that reach total depth

within Pennsylvanian-age formations are concentrated in the area of

Main Consolidated field (crescent shape in catchment 2 on Figure 10)

and west of the area of thermally-mature source rocks.  Almost 39,000

dry holes across the basin reach total depth in Mississippian-through-

Devonian-age formations (Figure 11). This is about 60% of all wells

drilled, an approximate percentage because some wells are reclassified

as dry after they are shut in, others are misreported or underreported,

and other factors tend to skew the data. 

 

More than 13,800 wells are listed as productive from Chesterian

reservoirs. This comprises 37% of all producing oil and (or) gas wells

in the basin; almost 100% are oil wells. More than 33% of oil and gas

wells in the basin produce from Valmeyeran age reservoirs; about 97%,

or 12,600, are oil wells (PI/Dwights WHCS data, 1996). Sandstone

reservoirs from the Chesterian and Valmeyeran are commonly interpreted

as being from fluvial, deltaic, shoreline, or tidal depositional

environments (Pryor and others, 1991). A typical Chesterian regressive

depositional cycle ( Figure 12) begins at the base with a marine shelf-

carbonate unit, followed by marine, shelf, or prodelta shale, and

topped by a sequence of sandstone and shale from shoreline, tidal-bar,

tidal-channel, delta or fluvial distributary, and lower delta-plain

environments (Pryor and others, 1991). There are seven primary

sandstone, shale, and carbonate lithofacies for Valmeyeran cycles

(Pryor and others, 1991). A Valmeyeran regressive depositional cycle is

shown on figure 13. Oil and gas wells from the Chesterian and the

Valmeyeran Series are shown on figures 14 and  15. Chesterian

reservoirs account for about 60% of the oil produced from the basin

(Howard, 1991). About 18% of basin oil production is from the Ste

Genevieve Limestone and 2% from sandstones of the Salem Formation

(Cluff and Lineback, 1981); these are the primary Valmeyeran

reservoirs.

 

Distribution of production from Silurian and Devonian-age formations

across the basin is illustrated on figure 16. These account for 2% and

5%, respectively, of oil reserves (Howard, 1991). There are about 3,000

oil and gas wells that produce from Silurian and Devonian reservoirs;

which is about 12% of the total (PI/Dwights WHCS data, 1996). The

scattered Silurian production is primarily in western and west-central

Illinois. Devonian production is widely scattered; primary reservoirs

are vuggy porous Geneva Dolomite. Minor amounts of natural gas may be

present in the deep part of the basin as an untapped resource

(Lineback, 1981).

 

 

Figure 9. Distribution of more than 4,700 wells with petroleum

production from Pennsylvanian-age reservoirs in the Illinois Basin.

Catchment 1 is labeled and catchments 2 through 7 are located clockwise

and sequentially from 1. Purple lines segregate each catchment.  An

irregular dark-reddish-brown line outlines the maximum extent of

Pennsylvanian-age formations. Well location data were derived from

PI/Dwights Well History Control System database (1996).  The large 104

KB image is named pennprod.jpg.

 

 

Figure 10. Shown are greater than 2,000 dry holes that reach total

depth within Pennsylvanian-age formations. Catchment 1 is labeled and

catchments 2 through 7 are located clockwise and sequentially from 1.

Purple lines segregate each catchment.  An irregular dark-reddish-brown

line outlines the maximum extent of Pennsylvanian-age formations. Well

location data were derived from PI/Dwights Well History Control System

database (1996).  The large 104KB image is called penndry.jpg .

 

 

Figure 11. Shown are more than 38,000 dry holes that reach total depth

within Mississippian-age or older formations. Catchment 1 is labeled

and catchments 2 through 7 are located clockwise and sequentially from

1. Purple lines segregate each catchment.  Subsurface or surface extent

of Chesterian-age formations is outlined by the irregular blue line.

Well location data were derived from PI/Dwights Well History Control

System database (1996).  The large 104KB image is called missdry.jpg .

 

 

Figure 12. Chesterian regressive depositional cycle is modified from

Pryor and others (1991, reprinted by permission of The American

Association of Petroleum Geologists and AAPG Data Systems (Datapages,

Inc.), whose permission is required for further use). Shown are

spontaneous potential (SP) and resistivity well-log signatures,

lithology, and depositional systems for an idealized shoaling-upward

regressive system; most cycles are bounded by disconformities (shown by

wavy horizontal lines). The large 16 KB image is named chesdep.jpg.

 

 

Figure 13. This Valmeyeran regressive depositional cycle is modified

from Pryor and others (1991, reprinted by permission of The American

Association of Petroleum Geologists and AAPG Data Systems (Datapages,

Inc.), whose permission is required for further use). Shown are

spontaneous potential (SP) and resistivity well-log signatures,

lithology, and depositional systems for an idealized upward-shoaling

regressive carbonate cycle. The large 36 KB image is named valmdep.jpg

.

 

 

Figure 14. Distribution of petroleum production from Chesterian-age

reservoirs in the Illinois Basin. Shown are more than 13,000 oil and

600 gas wells. Catchment 1 is labeled and catchments 2 through 7 are

located clockwise and sequentially from 1. Purple lines segregate each

catchment.  The irregular blue line outlines the maximum extent of

Chesterian-age formations. Well location data were derived from

PI/Dwights Well History Control System database (1996).  The large 112

KB image is named chesprod.jpg.

 

 

Figure 15.  This map shows wells that produce from units within the

Mississippian Valmeyeran Series. The catchments 1 through 7 are

labeled. Purple lines segregate each catchment.  The irregular dark-

green line outlines the maximum extent of Valmeyeran-age formations. 

Primary producing formations are Ste. Genevieve, Salem, and Aux Vases.

There are more than 12,000 oil wells (green) and 400 gas wells (red).

Well location data were derived from PI/Dwights Well History Control

System database (1996).  The large 107KB image is named valmprod.jpg .

 

 

Figure 16. Distribution of oil and gas wells from Silurian- and

Devonian-age formations. Shown are more than 2,700 oil and 100 gas

wells. Catchment 1 is labeled and catchments 2 through 7 are located

clockwise and sequentially from 1. Purple lines segregate each

catchment.  Well location data were derived from PI/Dwights Well

History Control System database (1996).  The large 93KB image is named

sildprod.jpg.

 

METHODS AND RESULTS

 

Source Rock Characterization

 

Characteristics of the source rocks and of the method of analysis used

in this study are detailed in Lewan and others (1995, 2002).  The New

Albany Shale (Figure 7) is composed of the following members. In

ascending order these are 1) Blocher, 2) Sylamore Sandstone, 3)

Selmier, 4) Grassy Creek, 5) Saverton, 6) Louisiana Limestone, 7)

Horton Creek, and 8) Hannibal (Atherton, Collinson, and Lineback, 1975;

Collinson and Atherton, 1975; Conkin and Conkin, 1973). An upper shale

composite of the New Albany Shale is sometimes called the Sweetland

Creek, Grassy Creek, Morgan Trail, Camp Run, and Clegg Creek Members.

To some extent, members grade laterally into others; because of erosion

and non-deposition there is no location in the basin that has all

members (Cluff and others, 1981). Isopach maps of source rock thickness

for wells across the basin comprised these members of the New Albany

Shale.  Figure 17 shows thickness of source-rock-quality New Albany

Shale across the generative basin.

 

 

Figure 17. Thickness of source-rock-quality New Albany Shale across the

generative basin, Illinois Basin. Isopach interval is 20 ft (6 m).

Greatest thickness of source rocks is the red "bulls eye" located near

the intersection of Illinois, Indiana, and Kentucky. This area is east

of the basin axis, and directly east of the "bulls eye" of greatest

maturation level. Catchment 1 is labeled and catchments 2 through 7 are

located clockwise and sequentially from 1. Purple lines segregate each

catchment.  Maximum extent of the New Albany Shale is shown by the dark

green line (modified from Lewan and others, 1995). Large-scale 122 KB

image is named srthick.jpg .

 

Initial thickness of the New Albany Shale, and of individual members,

was determined from published sources, and also by examination of well-

logs for the Selmier Member. Intervals assigned to source rocks are

characterized by API of 120 and greater on gamma ray logs.  Maps that

show total thickness of the Blocher and Selmier Members and of the

upper shale composite were traced and scanned (Cluff and Reibold, 1981;

Lineback, 1981; Lewan and others, 1985); scales were about 1 to 2.5

million. Resulting TIF-format graphics files were converted to Arc/Info

(Environmental System Research Institute, Inc., 1997) coverages and

saved as Lambert geographic projections.  Map polygons were assigned

average thicknesses for each member based on thickness values of

original contours. These polygon Arc/Info coverages were then converted

to grids to calculate thickness of member source rocks, and for the

total New Albany Shale.

 

Three Arc/Info coverages (map layers) that describe 1) HI contours, 2)

the source rock thickness, and 3) catchment boundaries were combined

into one file by using the intersection function in Arc/Info. The

spreadsheet that contained the combined attributes for each polygon was

then used to calculate amounts of expelled hydrocarbons. Greatest

thickness of source rocks is located in catchments 3 and 4, east of the

present-day axis of the basin. This is slightly east of the region

where the source rocks are the most-thermally-mature (Figure 5).

 

TOC determinations for eight cores at various maturity levels for the

Blocher Member show that 98% to 100% of this lower member is

hydrocarbon source rock. The effective thickness of the Blocher Member

was calculated by multiplying the total thickness by 0.99, a number

that approximates the percent that is source-rock quality. Effective

thickness of the Blocher Member upper composite was determined by

multiplying the total thickness by 0.97. Selmier Member effective

thickness was calculated by multiplying total thickness of this

interval by a grid that was created from point locations across the

basin. The three grids were added to derive contours for total

thickness of source-rock-quality of New Albany Shale.

 

Percent of source rock for the Selmier Member was variable; average for

61 wells that contained source-rock intervals was 58% of the total

member thickness.  Figure 18 shows the  thickness of the member across

the basin; figure 19 shows the percent of the member that exhibits high

levels of gamma radiation as indicated by API units of generally

greater than 120. Excluded from the source rock calculations were

intervals of the Selmier Member from 87 wells that exhibited low gamma

signatures characteristic of poor source rock potential; other members

in these wells were used in the analyses (well logs; Cluff and

Reinbold, 1981). Isopach thickness values for upper members of the New

Albany Shale (Hannibal and Saverton  Members) were further corrected to

account for source rock quality, based largely on TOC values. HI values

in the generative basin were assigned in Arc/Info to individual x-y

grid cells.

 

Thickness of the New Albany Shale, and of its individual members,

increases towards the basin depocenter in southern Illinois and Indiana

(Cluff and others, 1981; Devera and Hasenmueller, 1990) (Figures 18,

19). A second depocenter is located in northwestern Illinois in

catchment 7, just northwest of the saddle of 0 to 20 ft (0 to 6 m)

thick shale of the Selmier Member. The Selmier Member is about 200 ft

(61) thick in Hardin County, Illinois (Devera and Hasenmueller, 1990).

This is within the red contour fill in the southern tip of Illinois

(Figure 18). Percentages of source rock thickness that exhibit 120 API

units or greater gamma is highest along the basin axis (Figure 19).

Outlying high gamma percentages are commonly associated with thinner

intervals of Selmier, or may represent extrapolation outside the areas

of data control.

 

 

Figure 18. Isopach map of the Selmier Member of the New Albany Shale.

Contour interval is 10 ft. (3.0 m). Catchment 1 is labeled and

catchments 2 through 7 are located clockwise and sequentially from 1.

Purple lines segregate each catchment.  Maximum extent of the New

Albany Shale is shown by the dark green line (modified from Lewan and

others, 1995). The large 141 KB image is named selmiso.jpg.

 

 

Figure 19. Percent thickness of the Selmier Member of the New Albany

Shale that exhibits gamma signatures of 120 API units or greater.

Contour interval is 20%. Red line outlines the generative basin.

Catchment 1 is labeled and catchments 2 through 7 are located clockwise

and sequentially from 1. Purple lines segregate each catchment.  Basin

axis is the purple line that separates catchments a) 2 and 7, b) 3 and

6, and c) 4 and 5. Greatest percentage of source-rock quality shales

(thickest intervals of high gamma signature) are along the basin axis.

Maximum extent of the New Albany Shale is the dark green line (modified

from Lewan and others, 1995).  Sample locations are small inverted

triangles. These are more readily viewed on the large 131 KB

selmhga.jpg image.

 

Estimated Amounts of Generated and Produced Oil, Known Petroleum Volume

of Oil, and Original-Oil-In-Place

 

Cumulative production from Silurian through Pennsylvanian formations

across the basin through 1996 is 4.002 BBO; 2.624 BBO is from within

the generative basin. Half of the oil in the system, 49.6%, is produced

from only six fields; these are Clay City Consolidated, Lawrence,

Louden, Main Consolidated, New Harmony Consolidated, and Salem

Consolidated. Macke (1996) details an Illinois Basin-Post-New Albany

hydrocarbon play that includes Mississippian- through Pennsylvanian -

age formations across the basin. He lists cumulative production of 2.56

BBO for these formations, and 2.67 BBO cumulative for Silurian through

Pennsylvanian-age formations. This 2.67 BBO is considerably less than

the current 4.0 BBO cumulative production and may result primarily from

differences in the area of his basin and play boundaries. Macke's

(1996) Post-New Albany play covers an area of more than 34,000 sq. mi.;

API gravity of oil ranges from 22 to 42 degrees and averages 38

degrees. Oil contains about 0.3 percent sulfur.

Reported and calculated known petroleum volume in the basin for all

formations ranges from 3.57 to 4.30 BBO (Mast and Howard, 1991; Nehring

and Associates, 1995; PI/Dwights Corp., 1996). Our calculations, based

on these proprietary databases and published sources, result in a known

petroleum volume of 4.158 BBO; values of recoverable oil were available

for 210 of the 721 fields used in this analysis. There were originally

more than 1,700 fields across the basin but are now about 721, largely

because of consolidation of fields and under-recording of fields

completed early in the history of the basin and of small fields.

Reported and proprietary known petroleum volumes ranged from 100% to

192% over current cumulative oil production. Respective average and

median values for the scatter of data were 104.9% and 103.2%. The

103.2% recovery was used in the calculations because it better fit the

production histories of the remaining mostly smaller fields.

 

Mast and Howard (1991) indicate known petroleum volume of oil (their

"estimated ultimate recovery") from existing fields in the Illinois

Basin is 4.30 BBO, and that 7.7 BBO remains in place, some of which may

be produced through tertiary recovery methods. Gas production numbers

are not included because during the early history of drilling in the

basin huge quantities of associated dissolved gas were flared, and gas

production records were poorly kept. Bell and Cohee (1940) stated as

much as 1 MCF of associated-dissolved gas has been produced for each

barrel of oil recovered from fields in the Illinois Basin. Based on

this number, Mast and Howard (1991) suggest as much as 4 TCF of gas has

been flared and lost in the basin, or 667 MMBOE. Volume of produced

non-associated gas is about 250 BCFG (41.7 MMBOE); Bell and Cohee

(1940) indicated that lease condensate volumes are about 30 bbls for

each MMCFG produced.

 

The 4.158 BBO total known petroleum volume excludes oil from west of

the Sagamon arch, gas, and oil from Ordovician age formations. Also not

included are the in-place tar deposits of an estimated 3.4 billion

barrels of hydrocarbons (Noger, 1987; Crysdale and Schenk, 1988). These

were excluded because chemical analyses of the tar, particularly the

nickel and vanadium concentrations, indicated that the tar is derived

from a different source rock than the New Albany Shale (M. Lewan,

personal communication, 1998). Tar deposits within the Illinois Basin

are restricted to catchments Nos. 3 and 4. Tar occurs in sandstones of

Chesterian age in Crawford Co., Indiana (within catchment number 3,

Figure 14) (J. Rupp, personal communication 1998) and of Chesterian

through Pennsylvanian age in catchment 4 (Breckinridge, Hardin, McLean,

and Grayson counties, Kentucky)(Ball Associates, 1965). Tar deposits in

catchments 3 and 4 indicate that leakage of petroleum has occurred in

these catchments.

 

About 66% of the 4.158 BBO known petroleum volume, or 2.723 BBO, is

located within the generative part of the basin (Table 1). The

remaining 34% is concentrated within about 30 mi. (50 km) of the

generative area. Table 2 lists cumulative production, known petroleum

volume of oil, and original oil in place for the seven catchments in

the Illinois Basin. Also shown is production within and outside the

generative basin. Seventy to seventy-five percent of the production is

from shallow (less than 3,000 ft, 915 m) Chesterian and Pennsylvanian

reservoirs, 20% from Valmeyeran reservoirs, and much of the remaining

7% from Silurian- and Devonian-age formations (Howard, 1991; Mast and

Howard, 1991).

 

Table 1. Estimated amounts of hydrocarbons that have been generated and

produced from the New Albany Shale petroleum system in the Illinois

Basin. Shown are estimated volumes of hydrocarbons both within the area

of mature source rocks and outside this boundary. The thermally mature

region is defined by a hydrogen index (HI) value of 400. Included are

estimates of cumulative production, known petroleum volume of oil, and

original-oil-in-place (OOIP).  The known petroleum volume of oil is

36.22% of the OOIP of 11.45 BBO (billion barrels of oil). [If your view

does not read the HTML v. 3 format, the file is also saved as comma-

delimited ( ooipnum.csv), text ( ooipnum.txt), and EXCEL v 4.0 (

ooipnum.xls) formats.]

 

Table 2.  Catchment number (CN), cumulative production (CUM), known

petroleum volume (K VOL), and original oil in place (OOIP) values for

the New Albany Shale petroleum system.  Volumes are millions of barrels

of oil (MMBO).  "Within" and "outside" refer to location of produced,

in-place, and (or) recoverable oil within or outside the 400 HI contour

that encloses thermally mature source rocks.  The final column shows

the percent of oil production within the hydrocarbon generative area of

the Illinois Basin. [If your Web browser cannot view the below table,

it is also saved as comma-delimited ( oilprod.csv) and Microsoft EXCEL

v. 5.0 ( oilprod.xls) files. The external HTML table is named

oilprod.htm .]

 

Estimated original oil in place (OOIP) is 11.45 BBO; this is based on a

36.22% recovery ratio of the 4.158 BB known petroleum volume of oil.

The Mast and Howard (1991) estimate of OOIP for the basin is 12 BBO.

Their greater estimated volume results from incorporating both a larger

area and Ordovician production. We excluded production from Ordovician

formations and from wells west of the Sagamon Arch, because they are

not part of the New Albany Shale petroleum system. Neither Mast and

Howard (1991) nor our estimate includes hydrocarbons from tar deposits.

Mast and Howard (1991) included in their calculations the suggested 4

TCF of associated gas and 250 BCF of non-associated gas. The non-

associated gas fields they included are outside the boundaries of the

New Albany Shale petroleum system. We did not include their suggested 4

TCF of flared associated gas in our calculations. Our original-oil-in-

place (OOIP) percentages were determined primarily on Nehring and

Associates data on oil and gas fields (through 1995), Illinois State

Geological Survey reservoir studies, Department of Energy data, and

PI/Dwights production data on CD-ROM (through 1996). Cumulative

production of oil was derived from the above sources. OOIP numbers from

these sources for 38 oil fields across the study area range from 1.782

to 1,200 MMBO.

 

Mast and Howard (1991) assigned an overall recovery efficiency of about

34.3% for all fields inside, and some outside the Illinois Basin. They

indicated this percentage is probably too small for the Illinois Basin

alone for two reasons. The first is that recovery efficiency is greater

for Illinois Basin fields than for all fields in their study area,

which included all of Illinois, Indiana, and Kentucky. Second, use of

secondary recovery and other methods has increased production

efficiency in stripper and other wells. "By the end of 1983,

approximately one-third of cumulative oil production was attributable

to secondary recovery methods" (Mast and Howard, 1991). Their

recommendation of 36% recovery of OOIP agrees with our estimated

recovery percentage. Estimated recovery efficiency for all onshore U.S.

oil fields in 1980 was about 32.1% (American Petroleum Institute,

1980).

 

Estimates of Losses from Carrier Beds

 

Oil and gas can be lost during secondary migration of hydrocarbons. In

this study, estimates of residual losses and the analytical methods are

documented in Lewan and others (2002). Maps were created that showed

all wells in the Illinois Basin that contained reports of petroleum

production from or hydrocarbon shows in the principal reservoir rocks.

Information for these maps was collected from the PI/Dwights Well

History Control System (WHCS, 1996) and Production Data on CD-ROM

(1999) databases, and the Nehring database (1996). Included rock units

are the Valmeyeran Ste Genevieve Limestone and Aux Vases Sandstone, the

Chesterian Bethel and Cypress Sandstones, and three 'generic' units

consisting of Silurian, Devonian, and Pennsylvanian rocks. The

Pennsylvanian reservoir units were not divided into individual

formations because the areal extent of many of the named units in the

basin is limited. Silurian and Devonian well data were lumped at the

system level because these reservoirs make only a small contribution to

total basin petroleum production. Polygons of the maximum extent of

production and shows were plotted on these show maps. Arc/Info

coverages were then generated from the data and surfaces. The polygons

were taken as representative of the minimum areas through which

petroleum had migrated.

 

A data base that contains median porosity and permeability information

from core samples (Appendix 1, located in data/ fileform/porperm.xls)

was created from analyses supplied by the Illinois State and Indiana

Geological Surveys. From these point data, generalized basin porosity

contour maps were generated for the three Mississippian-age units. The

extent of these contours was limited by the polygons that represent the

extent of shows for the respective-age reservoir units. The 'generic'

units were assigned the following average porosities; 18% for

Pennsylvanian, 14% for Devonian, and 13% for Silurian (Howard, 1990).

The intersection function in Arc/Info was then used to combine the

attributes of the show map with those of the porosity contour maps for

each rock unit. A value of 1.5 ft (0.5 m) was used for the minimum

thickness of the carrier bed that was subjected to hydrocarbon

migration (Schowalter, 1979). Values of 1) porosity, 2) estimated

residual oil saturations, and 3) volume of carrier bed through which

petroleum moved were used to determine the residual loss of petroleum

for each polygon within the show area. These amounts were summed for a

total residual loss for each of the seven possible carrier units.

 

Factors That Influence/Control Estimation of Hydrocarbon Resources

The ultimate petroleum potential of a sedimentary basin is based on the

following equation from Lewan and others (1995, 2002). PC is petroleum

charge, which is the quantity of oil expelled from a mature source

rock, also referred to as a kitchen area (Lewan and others, 1995,

2002), or pod of active source rock (Magoon and Dow, 1994).   PL is

leakage of hydrocarbons due to eroded section, surface leakage of oil,

or secondary migration residual (Lewan and others, 2002).  Ultimate in-

place petroleum is the amount of petroleum that has been generated from

the source rocks, minus the amount lost (PL).  This is different from

OOIP, which is a measure of the original oil volume present in known

reservoirs; Lewan and others (2002) also refer to OOIP as "accountable

in-place oil". 

                 PC - PL = Ultimate In-Place Petroleum

 

A generalized list of factors that influence resource estimates

follows:

1) Economics - petroleum is present but in sub-economic or lesser

volumes due to

a. Price of oil and/or gas,

b. Distribution of oil and gas; scattered wells were sub-economic,

c. Mixing of oil and water.  Much of the oil around field margins is

located in thin units or admixed with other fluids and would not be

economic.

d. Loss of associated gas during production as a result of flaring. 

How much gas has been lost is unknown but the practice was common in

the Illinois Basin. Mast and Howard (1991) suggest as much as 4 TCF of

gas has been flared and lost in the basin.

e. Reporting. Most of the fields in the basin are older and reporting

practices were less rigorous in the past; this would be especially true

for infill wells, for smaller fields, and for those owned by smaller

operators. Older production is probably both under-reported and under-

compiled.

f. Non-discovery. While the basin center is extensively drilled for

Pennsylvanian through Mississippian formations, some of the fringe

areas are not. Some of the reasons for lack of discovery are sparse

drilling, non-detection of hydrocarbons in underpressured reservoirs or

within compartments, or not recognizing oil outside of the target

formations.

2)  Subsurface distribution and leakage of oil and gas

a. Loss of hydrocarbons updip or up fracture networks.

b. Loss of hydrocarbons from erosion following emplacement. This is

particularly important south of the Cottage Grove and Rough Creek-

Shawneetown fault systems.

c. Oil trapped within clays, in isolated shale stringers, and other

thin discontinuous units may not be factored into OOIP numbers because

they are based on production. In theory, the OOIP numbers take into

account these non-recoverable hydrocarbons.

3)  Field production practices

a. Formation was damaged during the drilling process and well had to be

abandoned (D & A).

b. Oil was produced but the reservoir was shut-in due to economics or

to technology. That is, the hydraulic fracturing or other process used

to complete the wells was inefficient at recovering hydrocarbons from

these heterogeneous reservoirs.

c. The field was shut in before the advent of secondary and tertiary

recovery processes. This would have resulted in an overall decrease in

production efficiency, perhaps to 28-30% of OOIP versus the 36.22% we

used in our calculations.

 

CONCLUSIONS

 

 This paper documents the analytical methods used in assessing oil and

gas reserves and resources for the material balance assessment by Lewan

and others (2002) of the New Albany-Chesterian petroleum system in the

Illinois Basin.  Included maps show the distribution of oil and gas and

non-productive wells for formations in the basin that are sourced from

the Upper Devonian and Lower Mississippian New Albany Shale, and tables

show data and results of the analyses.  Included on the 2D production

maps and the 3D images are the 7 hydrocarbon catchments of the basin

and the distribution of oil, gas, and non-productive wells for Silurian

through Pennsylvanian formations in the Illinois Basin.

 

The New Albany Shale in the Illinois Basin is the primary source for

oil and gas produced from the basin. The generative area of the

Illinois Basin is outlined by a hydrocarbon index value of 400; HI

values within the thermally mature portion of the basin range from 10

to 400 mg/g TOC (Appendix 2, HI_TOC.xls). About 66% of the produced oil

occurs within the generative basin, which suggests that oil primarily

migrated upwards through faults and fractures into overlying reservoir

strata. Remaining production is concentrated within about 30 mi. (50

km) of the generative area, suggesting limited lateral migration. The

influence of lateral migration through porous carrier beds may be

important in large oil fields such as Louden and Main Consolidated, all

or parts of which lie outside the generative basin.

 

Silurian through Pennsylvanian rocks in the Illinois Basin contain

4.158 BB known petroleum volume of oil, and have produced 4.002 BBO.

Estimated original oil in place (OOIP) is 11.45 BBO.  Known petroleum

volume is 36.22% of the OOIP. Excluded from the calculations were areas

west of the Sagamon arch, which are outside the generative basin, may

have a different migration history, and may contain petroleum

production from Ordovician rocks, which have a different source. Also

excluded was associated dissolved gas; which is mainly located outside

the assessment area, was primarily flared across the basin, and of

which few records were kept.

 

SELECTED REFERENCES

 

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Bethke, C. M., Reed, J. D., and Oltz, D.F., 1991, Long-range petroleum

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Cluff, R.M., and Lineback, J.A., 1981, Middle Mississippian carbonates

of the Illinois Basin: a seminar and core workshop: Illinois Geological

Society, 88p.

 

Cluff, R.M., and Reinbold, M.L., 1981, The New Albany Shale Group of

Illinois: Illinois State Geological Survey Publication C518, 4 plates.

 

Cluff, R.M., Reinbold, M.L., and Lineback, J.A., 1981, The New Albany

Shale Group of Illinois: Illinois State Geological Survey Circular 518,

83 p.

 

Collinson, C. and Atherton, E., 1975, Devonian system, in Willman,

H.B., Atherton, E., Bushbach, T.B., Collinson, C., Frye, J.C., Hopkins,

M.E., Lineback, J.E., and Simon, J.P., eds., Handbook of Illinois

stratigraphy: Illinois State Geological Survey Bulletin 95, p. 104-123.

 

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determination of the Devonian-Mississippian boundary in the type Lower

Mississippian area of North America: University of Louisville, Sudies

in Paleontology and Stratigraphy, n. 1, 36 p.

 

Damberger, H.H, 1971, Coalification pattern of the Illinois Basin:

Economic Geology, v. 66, n. 3, p. 488-494.

 

Devera, J.A., and Hasenmueller, N.R., 1990, Kaskaskia Sequence - Middle

and Upper Devonian Series Through Mississippian Kinderhookian Series,

in Leighton, M.W., Kolata, D.R., Oltz, D.F., and Eidel, J.J., eds.,

Interior Cratonic Basins: American Association of Petroleum Geologists

Memoir 51, p. 113-123.

Dictionary of Geological Terms, 1984, Bates, R.L., and Jackson, J.A.,

eds.:  American Geological Institute, Doubleday Dell Publishing, 666

Fifth Ave., New York, New York, 571 p.

 

Ebanks, W.J., Jr., 1987, Geology in enhanced oil recovery; in Tillman,

R.W. and Weber, K.J. eds., Reservoir Sedimentology: Society of Economic

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Energy Information Administration, 1987, U.S. crude oil, natural gas

and natural gas liquids reserves - 1986 annual report: Department of

Energy/Energy Information Administration 0216 (86), 98 p.

 

Environmental System Research Institute, Inc., 1997, ArcInfo, version

7.0, geographic information system software: 380 New York Street,

Redlands, California.

 

Espitalie, J.M., Laporte, J.L., Madec, M., Marguis, F., Leplat, P.,

Paulet, J., and Boutefeu, A., 1977a, Methode rapide de caracterisation

des roches meres de leur potentiel petrolier et de leur degre

d'evolution: Rev. Inst. Franc. Petrole, v. 32, p. 23-42.

 

Espitalie, J.M., Madec, M., Tissot, B., Mening, J.J., and Leplat, P.,

1977b, Source rock characterization method for petroleum exploration:

Proceedings of the 9th Annual Offshore Technology Conference, v. 3, p.

439-448.

 

Grube, J. P., 1992, Reservoir characterization and improved oil

recovery from multiple bar sandstones, Cypress Formation, Tamaroa and

Tamaroa South fields, Perry County, Illinois; Illinois State Geologic

Survey, IP 138, 49 p. 2 plates.

 

Hatch, J.R., Risatti, J.B., and King, J.D., 1991, Geochemistry of

Illinois Basin oils and hydrocarbon source rocks, in Leighton, M.W.,

Kolata, D.R., Oltz, D.F. and Eidel, J.J., eds., Interior Cratonic

Basins: American Association of Petroleum Geologists Memoir 51, p. 295-

298.

 

Higley, D.K., Pantea, M.P., and Slatt, R.M., 1997, 3-D reservoir

characterization of the House Creek oil field, Powder River Basin,

Wyoming, V 1.00: U.S. Geological Survey Digital Data Series 33, 200 MB.   

http://greenwood.cr.usgs.gov/pub/dds/dds-033/USGS_3D/homepage.htm

 

Howard, R.H., 1991, Hydrocarbon reservoir distribution in the Illinois

Basin, in Leighton, M.W., Kolata, D.R., Oltz, D.F. and Eidel, J.J.,

eds., Interior Cratonic Basins: American Association of Petroleum

Geologists Memoir 51, p. 299-327.

 

Howard, R. H., and Whitacker, S. T., 1990, Fluvial-estuarine valley

fill at the Mississippian-Pennsylvanian unconformity, Main Consolidated

field, Illinois, in Barwis, J.H., McPherson, J.G., and Studlick,

J.R.J., eds., Casebooks in Earth Sciences: Springer-Verlag, New York,

p. 319-341.

 

Klett, T.R., Schmoker, J.W., Charpentier, R.R., Ahlbradt, T.S., and

Ulmishek, G.F., 2000, Glossary, in U.S. Geological Survey World Energy

Assessment Team, U. S. Geological Survey World Petroleum Assessment

2000-Description and Results: U.S. Geological Survey DDS 60, 4 CD-ROMs.

http://greenwood.cr.usgs.gov/energy/WorldEnergy/DDS-60

 

Kolata, D.R., and Nelson, W.J., 1991, Tectonic history of the Illinois

Basin, in Leighton, M.W., Kolata, D.R., Oltz, D.F. and Eidel, J.J.,

eds., Interior Cratonic Basins: American Association of Petroleum

Geologists Memoir 51, p. 263-285.

 

Lewan, M.D., 1987, Petrographic study of primary petroleum migration in

Woodford Shale and related rock units, in Doligez, B., ed., Migration

of Hydrocarbons in Sedimentary Basins: Paris, Editions Technip, p. 113-

130.

 

Lewan, M.D., 1993, Laboratory simulation of petroleum formation by

hydrous pyrolysis: American Chemical Society, Division of Fuel

Chemistry Preprints, v. 37, no. 4., p. 1643-1648.

 

Lewan, M.D., Comer, J.B., Hamilton-Smith, T., Hasenmueller, N.R.,

Guthrie, J.M., Hatch, J.R., Gautier, D.L., and Frankie, W.T., 1995,

Feasibility study of material-balance assessment of petroleum from the

New Albany Shale in the Illinois Basin: U.S. Geological Survey Bulletin

2137, 31 p.

 

Lewan, M.D., Henry, M.E., Higley, D.K., and Pitman, J.K., (2002),

Material-balance assessment of the New Albany-Chesterian petroleum

system of the Illinois Basin: American Association of Petroleum

Geologists Bulletin, v. 85, no. 5, p. 745-777.

 

Lineback, J.A., 1981, Coordinated study of the Devonian black shale in

the Illinois Basin: Illinois, Indiana, and western Kentucky: final

report, 1980: Illinois State Geological Survey Contract/Grant Report

1981-1, 36 p.

 

Macke, D., L., 1996, Illinois Basin Province (064), in Gautier, D.L.,

Dolton, G.L., Takahashi, K.I. and Varnes, K.L., eds., 1995 National

Assessment of United States Oil and Gas Resources - Results,

Methodology, and Supporting Data: U.S. Geological Survey Digital Data

Series DDS-30, Release 2, 1 CD-ROM.

 

Magoon, L.B., and Dow, W.G., 1994, The petroleum system, in L.B.

Magoon, and W.G. Dow, eds., The Petroleum System - from Source to Trap:

American Association of Petroleum Geologists Memoir 60, p. 3-23.

 

Mast, R.F., and Howard, R.H., 1991, Oil and gas production and recovery

estimates in the Illinois Basin, in Leighton, M.W., Kolata, D.R., Oltz,

D.F. and Eidel, eds., Interior Cratonic Basins: American Association of

Petroleum Geologists Memoir 51, p. 295-298.

 

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Leighton, M.W., Kolata, D.R., Oltz, D.F. and Eidel, J.J., eds.,

Interior Cratonic Basins: Tulsa, American Association of Petroleum

Geologists Memoir 51, p. 209-243.

 

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in southern Illinois: Illinois State Geological Survey Circular 522, 65

p.

 

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1985-3, and U.S. Nuclear Regulatory Commission NUREG/CR-4333, 93 p.

 

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IHS Energy, 15 Inverness Drive East, Englewood, CO 80112.

 

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Energy, 15 Inverness Drive East, Englewood, CO 80112.

 

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W.L.M., 1991, Geologic controls on porosity in Mississippian Limestone

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Kolata, D.R., Oltz, D.F. and Eidel, J.J., eds., Interior Cratonic

Basins: American Association of Petroleum Geologists Memoir 51, p. 329-

360.

 

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geology and geochemistry of Devonian shales in south and west-central

Kentucky, in Proceedings of the 1983 Eastern Oil Shale Symposium,

November 13-16, 1983, Lexington, Ky., University of Kentucky Institute

for Mining and Minerals Research, p. 59-71.

 

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and entrapment: American Association of Petroleum Geologists Bulletin,

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workshop and field trip; Illinois Geological Society and Illinois State

Geological Survey publication, 67 p.

 

Seyler, B., Hughes, R.E., and Beaty, D.S., 1995, The role of diagenesis

in Aux Vases and Cypress Sandstone reservoir development; draft copy,

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Shaver, R.H., R.H., Mikulic, D.G., Collinson, C., Atherton, E., Baxter,

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Sargent, M.L., Trask, C.B., Willman, H.B., and Schwalb, H.K., 1985,

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of stratigraphic units of North America: American Association of

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Illinois State Geological Survey Circular 519, 22p.

 

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Atherton, E., Collinson, C., Lineback, J.A., and Buschbach, T.C., 1967,

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ACKNOWLEDGEMENTS

 

Keith Kirk, previously of the Office of Surface Mining, and other

Office of Surface Mining personnel, Denver, Colorado, were kind enough

to allow us access to their 3-D EarthVision computer software. The

publication benefited from reviews by Tom Judkins, Joe Hatch, Mike

Pantea, and Kathy Varnes of the U.S. Geological Survey.

++++++++++++++++++++++++++++++++++++++++++++++

U.S. Department of the Interior

U.S. Geological Survey

 

THE NEW ALBANY SHALE PETROLEUM SYSTEM, ILLINOIS BASIN - DATA AND MAP

IMAGE ARCHIVE FROM THE MATERIAL-BALANCE ASSESSMENT

 

The two sets of data that are located in the "data" sub-directory are

porperm.xls and HI_TOC.xls. All data files are saved in Microsoft EXCEL

version 5.0 as v97 and 5.0/95 Workbooks, as space-delimited files

(*.txt), and comma-delimited data (*.csv). File contents and examples

are shown and explained below.

 

Table 3. Below is a sample from the porperm.xls file. The data are also

saved as comma-delimited ( porperm.csv ) and space-delimited (

porperm.txt ) formats. Files are located in the "data" sub-directory.

Three-hundred and seventy-seven core reports were used to determine

median values of porosity, permeability, and the percent oil and water

saturation for cored intervals of the following Mississippian-age

formations: Aux Vases, Bethel, Cypress, and the McCloskey unit of the

Saint Genevieve. Figure 7 is a stratigraphic column of these

formations. Percents of oil and water saturation are generally

inaccurate due to water washing and/or contamination of the core during

drilling and recovery.

 

VARIABLES FOR PORPERM FILES ARE:

* ID = Identification code for that cored interval

* Longitude = Geographic reference point, values are degrees of arc. 

Data are derived primarily from State sources.

* Latitude = Geographic reference point, values are degrees of arc. 

Data are derived primarily from State sources. 

* Form = Cored stratigraphic interval. AXVS = Aux Vases, BTHL = Bethel,

CPRS = Cypress, MCLK = McCloskey

* Depthft = Median depth in feet of the core

* Hperm = Median horizontal permeability, in millidarcies

* Porosity = Median porosity of the cored interval, in percent

* %Oil = Median percent of oil saturation in the cored formation

* %Water = Median percent of water saturation in the core.

* Well Name = Name of the well on the core report

* Field Name = Name of the oil field, or "wildcat" is entered if there

is no field

* TRS = Township, range, and section location of the well from the core

report. This is written in several formats and can include quarter

sections.

 

Table 4. The below sample from the HI_TOC files shows geochemical

statistics for samples from the New Albany Shale. HI_TOC.xls file is

saved in Microsoft EXCEL version 5.0 as v97 and 5.0/95 Workbook. The

file is also saved in space-delimited (HI_TOC.txt) and comma-delimited

formats (HI_TOC.cvs). Analytical methods are detailed and assessed in

Lewan et al. (1995, 2002), and very briefly summarized here. Total

organic carbon content (TOC) of hydrocarbon source rocks is primarily

determined using Rock-Eval pyrolysis. This technique involves heating

about 50 to 150 mg of powdered rock in a crucible under anhydrous

conditions. The oven is continuously swept by flowing helium at low

pressures, and the sample is heated isothermally, followed by a

programmed rate of heating. Pyrolysis of the sample at a constant

temperature of about 250 degrees C for 3 to 5 minutes distills organic

compounds from C1 (one carbon atom and attached hydrogen atoms) to

about C32. Volatilized products are swept with helium into a flame

ionization detector (FID) for quantification of contained hydrocarbons.

These pyrolyzed hydrocarbons are considered to be bound to the organic

matter in the sample and are designated as "S1" (S subscript 1)

hydrocarbons. Programmed heating from 250 to 600 degrees C at a rate of

25 degrees C/minute cracks the kerogen and heavy bitumen. This yields

organic compounds, water, carbon dioxide, and other gases. Half of the

flow of produced molecules is sent to the FID to measure hydrocarbon

compounds; these are designated "S2" (S subscript 2), generated

hydrocarbons. The other half of the flow is sent to a carbon dioxide

trap that is heated at 250 to 390 degrees C. Compounds in the carbon

dioxide trap are heated and resulting gas is measured by a thermal

conductivity detector (TCD); these hydrocarbons are designated as "S3"

(S subscript 3). Evolved carbon monoxide (CO) is not measured. The

crucible is then moved to another furnace where it is heated to about

590 degrees C in air (oxidizing atmosphere). The evolved carbon dioxide

is measured by the TCD.

 

VARIABLES FOR HI_TOC FILES OF THE NEW ALBANY SHALE ARE:

* State = The State in the United States from which the sample

originated (IL=Illinois, IN=Indiana, KY=Kentucky)

* Latitude = Geographic reference point, values are degrees of arc. 

Data are primarily from State records.

* Longitude = Geographic reference point, values are degrees of arc. 

Data are primarily from State records.

* Tmax = Tmax results (degrees C) from Rock Eval or hydrous pyrolysis

* PI = Production index (Lewan et al., 2002)

* TOC = Total organic carbon content (weight percent) of the New Albany

Shale source rocks

* HI = Hydrogen index values determined from Rock Eval or hydrous

pyrolysis ((mg S2 hydrocarbons)/TOC).

* Sample_No = Sequential numbers assigned to each sample. Numbers for

the 262 samples in the file range up to 318. Not all results are

included, some were for different formations or were outside the study

area.

* Sample_ID = Identification code for that sample location. Some

Kentucky wells instead have the well name.

 

++++++++++++++++++++++++++++++++++++++++++++++

Glossary - THE NEW ALBANY SHALE PETROLEUM SYSTEM, ILLINOIS BASIN;

RESOURCE ESTIMATES BY CATCHMENT

 

Authigenic

Generated or formed in place. Specifically used with rock minerals and

other constituents that were derived locally, and of minerals that

precipitated at the same time, or subsequent, to the rock in which they

are found.

 

ASCII

(American Standard Code for Information Interchange) A standard format

for storing and transmitting data. A set of binary numbers that

represent the alphabet, punctuation, numbers, and symbols that are used

for text and communication protocols.

 

Binary

A file format consisting of machine-readable executable code or binary

data, as opposed to ASCII text files.

 

BinHex

A file conversion format that converts binary files to ASCII text

files.

 

Biostratigraphy

Ages, differentiation, and correlation of rock intervals based on the

study of contained fossils.

 

Bioturbated

Sediment that has been extensively reworked by worms, crustaceans, or

other organisms. Burrows and other evidence of reworking are commonly

minor due to the biologic activity.

 

Bug

Commonly indicates a software or other computer-based error.

 

Case sensitive

Refers to upper and lower case letters. UNIX is case sensitive, meaning

that names of document links and file names must be identical. A

program accessing "Cat.GIF" would not find the same file were it named

"cat.GIF."

 

Concretions

Hard round, oval, or other-shaped mass of mineral or aggregate matter

of varied sizes. Commonly forms by chemical precipitation around a

nucleus or center, or replacement of precursor organic or inorganic

material. An example is siderite (iron, calcium carbonate) concretions.

 

Detrital

Formed from detritus of preexisting rock. This is particularly for

rocks, minerals, and sediments composed of precursor components.

 

Diachronous

A single rock unit that exhibits various ages in different areas. A

sedimentary formation, such as marine sands, that formed during

transgression or regression of the shoreline, being progressively

younger in the direction that the sea level is moving.

 

Diagenesis

Changes that influence sediments after deposition. These include

compaction, cementation, chemical alteration, dissolution, and

precipitation of constituents. Excluded are surficial weathering, and

metamorphism of preexisting sediments.

 

Dissolution

A void space or cavity in or between rocks that resulted from solution

of part of the rock material.

 

Document window

Scrollable WWW browser window in which documents, slide shows, and

movies are viewed.

 

File Transfer Protocol (FTP)

File Transfer Protocol is commonly used to transfer files from one

computer platform to another.

 

Flow unit

In petroleum geology, reservoir zones that exhibit similar fluid flow,

porosity/permeability, reservoir potential, and production

characteristics. The flow-unit definition includes a "volume of rock

subdivided according to geological and petrophysical properties that

influence the flow of fluids through it" (Ebanks, 1987).

 

Folder

Directory, sub-directory, and folder are used interchangeably to show

addresses of files on this CD-ROM. 

 

FTP (File Transfer Protocol)

File Transfer Protocol is commonly used to transfer files from one

computer platform to another.

 

GIF (Graphics Interchange Format)

GIF is a graphics file, commonly with the .gif or .GIF ending. The

acronym refers to the Graphics Interchange format developed by

CompuServe, Inc. This graphics format is used on numerous computer

platforms and systems. GIF files can be for inline and movie images.

 

Heterogeneity

The state or quality of being nonuniform, having dissimilar elements,

not homogeneous. For example, a unit composed of interbedded thin- and

thick-bedded sandstones and mudstones is heterogeneous.

 

Home page

The initial screen or graphic image in which links to related

information are listed. A document that the user specifies for network

browsing software to display, commonly when the software program is

started.

 

HTML (Hypertext Markup Language)

Acronym for Hypertext Markup Language. HTML files on this CD-ROM follow

the 8.3 PC/DOS format. One version of this file, for example, is named

glossary.htm.

 

Hydrogen index (HI=S2/TOC (mg hydrocarbons/g organic carbon))

The hydrocarbon generative potential of a rock normalized to TOC is

correlative with the H/C ratio of the kerogen. HI is an indicator of

kerogen type and whether the source rock is oil or gas prone. Values

generally range from 0 to 900.

 

Image

Refers to still image data. Subtypes recognized by graphics programs

include JPEG, GIF, RGB, TAR, TIFF, X-PICT (PICT), X-XBM (X bitmap

image), and other formats.

 

JPEG (Joint Photographic Experts Group)

Acronym for Joint Photographic Experts Group, an image-compression

format used to transfer color images over computer networks.

 

Known Petroleum Volume

The sum of cumulative production and remaining reserves.  Also called

estimated total recoverable volume (sometimes called "ultimate

recoverable reserves" or "estimated ultimate recovery").  Commonly

reported as millions of barrels of oil (MMBO), or million barrels of

oil equivalent (MMBOE) when both oil and gas production and reserves

are evaluated; the equivalent refers to conversion of gas to oil

volume.  Modified from Klett and others (2000).

 

Laminar bedding

1) Finest stratification of shale or fine-grained sandstone bedding, 2)

thin alternating layers of differing composition, and 3) laminae, such

as in shale, that can be split into thin layers.

 

Meniscus

The curved upper surface of a nonturbulent liquid in a container. A

crescent-shaped body. A concavo-convex lens.

 

Minus-cement porosity

The percent volume of void space in a rock, added with volume of

cements and other post-depositional pore-filling compounds. This is

used as an estimate of porosity during the time of deposition of the

rock.

 

MOV

File type of a single-forked stand-alone QuickTime movie.

 

MPG, MPEG, CMPEG

Moving Pictures Expert Group movie file type used primarily for PC/DOS

and UNIX platforms. Special viewing applications are required to run

MPG movies on your computer.

 

Overgrowth

Secondary material precipitated around a crystal grain of the same

composition. Both grain and cement are in optical and crystallographic

continuity.

 

Paragenesis

A sequential order of rock alteration, such as, compaction,

precipitation of minerals, dissolution of grains and cements, and

similar processes.

 

Permeability

The capacity or ability of a porous medium, such as rock or soil, to

transmit fluid; an indication of the rate of diffusion of a fluid under

unequal pressure. The common unit of measure is the millidarcy (mD).

 

Petroleum System

The basic geologic unit used to assess oil and gas reserves and

resources and includes all genetically related petroleum that occurs in

shows and accumulations that (1) has been generated by a pod or by

closely related pods of mature source rock, and (2) exists within a

limited mappable geologic space, along with the other essential

mappable geologic/geochemical elements (source, reservoir, seal, and

overburden rocks) that control the fundamental processes of generation,

expulsion, migration, entrapment, and preservation of petroleum

(modified from Magoon and Dow, 1994). 

 

Production Index (PI= S1/(S1+S2))

During thermal maturation of a source rock the S1 hydrocarbons increase

at the expense of S2 hydrocarbons, with an associated increase in PI.

PI is an indicator of the level of thermal maturity of source rocks. A

rock sample that is oil-stained or has organic contamination will

exhibit an anomalously high PI. Values range from 0.0 to generally less

than 0.4.

 

Planar bedded

Lying or arranged in approximately parallel planes. Bedding in which

the lower surface is a beveled erosional contact; cross bedding is

characterized by planar foreset beds. 

 

Porosity

The percentage of bulk volume of a rock or other object that is

occupied by void space, whether isolated or connected. Porosity is

further subdivided into effective (or connected) pores, primary,

secondary, and minus-cement categories. Primary porosity includes all

depositional pore spaces; secondary porosity records the volume of void

space resulting from dissolution and (or) fracturing of the rock or

sediment. Minus-cement porosity category combines intergranular primary

porosity and secondary porosity, in addition to authigenic cements and

clays, as an estimate of the amount of porosity at the time of

lithification; porosity resulting from intragranular dissolution is

excluded

 

QuickTime

A digital video standard developed by Apple Computer for PC/Windows and

Apple computers. The QuickTime extension file is inserted into the

Apple System Folder, and special viewing applications are required to

view QuickTime "movies."

 

Range

1) Any series of contiguous townships of the U.S. Public Land Survey

system. These are aligned parallel to a principal meridian and numbered

consecutively in an east-west direction from the meridian. 2) mountain

range. 3) The numerical difference between a series highest and lowest

values. 4) stratigraphic range. 5) A geographic area over which an

organism or group of organisms is located.

 

Ravinement

A break in sedimentation resulting primarily from erosion. An example

is a disconformity resulting from marine transgression and erosion of

precursor sediments. Formation of a gully or ravine.

 

Radiometry

Methods of calculating an age for geologic materials by measuring the

amounts of short-half-life radioactive elements, such as carbon-14, or

of long-half-life radioactive elements plus their decay products, such

as potassium-40/argon-40.

 

Regression

(Simply) The local or widespread retreat of seas from land surfaces and

resulting changes in erosion and depositional patterns of strata.

 

Rock-Eval Pyrolysis

An open-system method of heating 10-20 milligrams of powdered rock at

300 to 600 degrees C over 15 to 30 minutes.  Vaporized S1 and S2

products (below) that are generated from the sample during the heating

are swept from the oven with a carrier gas over a flame ionization

detector; the purpose is to quantify yields of generated hydrocarbons

(Espitalie and others, 1977a, b).

 

S1

Free hydrocarbons (HC, hydrogen plus carbon molecules) in the rock.

Measured as mg HC/g rock (milligrams of hydrocarbons per gram of rock

sample). This approximates the gas, oil, and bitumen content of the

rock, up to about C33 (thirty-three carbon atoms with attached hydrogen

atoms).

 

S2

Hydrocarbons that are generated by pyrolytic degradation (cracking

under high heat) of the kerogen and any remaining free hydrocarbon

chains greater than C33 (thirty-three carbon atoms with attached

hydrogen atoms) (heavy bitumen) in the sample (mg HC/g rock). Common

values range from 0 to 40 mg/g.

 

SEA (Self-Extracting Archive)

Self-extracting archive (SEA). These compressed files contain one or

more files and (or) programs. SEA s are generally decompressed by

double clicking on the name or icon. Further instructions are given

during the decompression process.

 

Secondary porosity

Porosity developed in a rock subsequent to its emplacement or

deposition. Processes are mostly dissolution of grains, cements, and

other constituents due to changes in pressure and (or) pore-fluid

composition.

 

Section

1) One of the 36 units that make up a township, and are generally one

mile square. 2) An exposed vertical or inclined surface, such as a

cliff or quarry face. 3) geologic term used for a columnar section,

type section or thin section.

 

TGA (TARGA)

TARGA image file format; this commonly has a .tga or .TGA ending.

TIFF (Tagged Image File Format)

Acronym for Tagged Image File Format, a graphic file format developed

by Aldus and Microsoft. TIFF is used as an image transfer format on

computer networks.

 

Tmax

Temperature (degrees C) during which the maximum amount of S2

hydrocarbons is generated from a rock sample. Tmax values are functions

of kerogen type and levels of thermal maturity. This is a measure of

the degree of thermal maturity of potential hydrocarbon source rocks.

Total organic carbon (TOC = RC + PC = Wt % organic C in the rock)

The TOC is the sum of the residual carbon (RC) and the pyrolyzable

carbon (PC). Residual Carbon (RC=0.1*S4) is determined from the amount

of carbon dioxide that is evolved during combustion of the rock sample.

This assumes complete combustion with no contamination by carbonate

carbon. The organic carbon represented by the carbon dioxide from

pyrolysis (S3) is fairly small and is excluded from the TOC

calculation.

 

Transgression

(Simply) The advance or spread of seas over land surfaces which cause

changes in erosion and depositional patterns of marine and non-marine

strata.

 

Tabular cross bedding

Cross-bedded units that are bounded by planar, essentially parallel,

surfaces to form tabular sandstone bodies.

 

Township

A unit of survey of the U.S. Public Land Survey. It is an area bounded

on the east and west by meridians located about 6 miles apart. A

township is normally a square that is subdivided into 36 sections, each

of which is approximately 1 mile square. Township, range, and section

locations are shown on most topographic maps, for example.

 

Trough cross bedding

Cross-bedding in which the lower surfaces are curved erosional contacts

which result from scour and subsequent deposition.

 

URL (Uniform Resource Locator)

The acronym stands for Uniform Resource Locator, the addressing

standard on the WWW. The URL contains information about the location,

method of access, and path of files to be viewed.

 

World Wide Web (WWW)

The hypermedia document network system, abbreviated as WWW. WWW can be

accessed over the Internet using Web browser software.

 

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