Results from coalbed methane drilling in 

Winn Parish, Louisiana 

By Paul C. Hackley1, Peter D. Warwick1, F. Clayton Breland, Jr.2, Troy E. 

Richard3

, and Kirk Ross4 

This report is preliminary and has not been reviewed for conformity with U.S. Geological Survey editorial standards 

and stratigraphic nomenclature. Any use of trade, product, or firm names is for descriptive purposes only, and 

does not imply endorsement by the U.S. Geological Survey. 

Open-File Report 2007-1061 

1

U.S. Geological Survey, Reston, VA 20192

2

Louisiana Geological Survey, Basin Research Energy Section, Baton Rouge, LA 

70803 

3

Hilcorp Energy Company

4

Vintage Petroleum, Inc. 

U.S. Department of the Interior 

U.S. Geological Survey 
U.S. Department of the Interior 

Dirk A. Kempthorne, Secretary 

U.S. Geological Survey 

Mark D. Myers, Director 

U.S. Geological Survey, Reston, Virginia: 2007 

For product and ordering information: 

World Wide Web: http://www.usgs.gov/pubprod 

Telephone: 1-888-ASK-USGS
 

For more information on the USGS—the Federal source for science about the Earth, 

its natural and living resources, natural hazards, and the environment: 

World Wide Web: http://www.usgs.gov 

Telephone: 1-888-ASK-USGS 

Suggested citation: 

Hackley, P.C., Warwick, P.D., Breland, F.C., Jr., Richard, T.E., and Ross, K., 2007, Results from

coalbed methane drilling in Winn Parish, Louisiana: U.S. Geological Survey Open-File Report 

2007-1061, 45 p. http://www.pubs.usgs.gov/of/2007/1061. 

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

endorsement by the U.S. Government. 

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

copyright owners to reproduce any copyrighted material contained within this report. 

ii 
TABLE OF CONTENTS 

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

Analytical Methods .......................................................................................................................................................1
 

Coal Samples...............................................................................................................................................................1
 

Gas Desorption Analyses.............................................................................................................................................1
 

Coal Quality Analyses ..................................................................................................................................................2
 

Petrographic Analyses .................................................................................................................................................2
 

Methane Adsorption Analyses .....................................................................................................................................2
 

Produced Water Analyses............................................................................................................................................3
 

Gas-in-place Calculations ............................................................................................................................................3
 

Acknowledgements ......................................................................................................................................................3
 

References Cited .........................................................................................................................................................3
 

LIST OF FIGURES 

Figure 1. Location of CZ Fee A No. 114 CBM well......................................................................................................4
 

Figure 2. E-logs and interpreted stratigraphy of CZ Fee A No. 114 CBM well............................................................5
 

Figure 3. Ash yield (as-received) versus bulk density, CZ Fee A No. 114 CBM well samples ...................................6
 

Figure 4. Raw gas content versus bulk density, CZ Fee A No. 114 CBM well samples .............................................7
 

Figure 5. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM well, sample 1...........8
 

Figure 6. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM well, sample 2...........9
 

Figure 7. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM well, sample 3.........10
 

Figure 8. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM well, sample 9.........11
 

Figure 9. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM well, sample 10.......12
 

Figure 10. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM well, sample 11.....13
 

Figure 11. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM well, sample 12.....14
 

Figure 12. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM well, sample 13.....15
 

Figure 13. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 4, raw basis..................................16
 

Figure 14. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 4, dry basis ..................................16
 

Figure 15. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 4, dry, ash-free basis ...................17
 

Figure 16. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 7, raw basis..................................17
 

Figure 17. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 7, dry basis ..................................18
 

Figure 18. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 7, dry, ash-free basis ...................18
 

Figure 19. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 11, raw-basis ...............................19
 

Figure 20. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 11, dry basis ................................19
 

Figure 21. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 11, dry, ash-free basis .................20
 

Figure 22. Methane adsorption isotherms and measured gas content, CZ Fee A No. 114 CBM well, as-analyzed 

basis...........................................................................................................................................................................21
 

LIST OF TABLES 

Table 1. General information for CZ Fee A No. 114 CBM well, Winn Parish, LA......................................................22
 

Table 2. Gas desorption data for CZ Fee A No. 114 CBM well.................................................................................23
 

Table 3. Coal quality data for CZ Fee A No. 114 CBM well, sample 4 (2,679.0-2,681.0 ft). .....................................24
 

Table 4. Coal quality data for CZ Fee A No. 114 CBM well, sample 7 (2,731.0-2,732.0 ft). .....................................25
 

Table 5. Coal quality data for CZ Fee A No. 114 CBM well, sample 11 (2,938.0-2,939.0 ft). ...................................26
 

Table 6. Petrographic data for CZ Fee A No. 114 CBM well, sample 4 (2,679.0-2,681.0 ft). ...................................27
 

Table 7. Petrographic data for CZ Fee A No. 114 CBM well, sample 7 (2,731.0-2,732.0 ft). ...................................28
 

Table 8. Petrographic data for CZ Fee A No. 114 CBM well, sample 11 (2,938.0-2,939.0 ft). .................................29
 

Table 9. Vitrinite reflectance data for CZ Fee A No. 114 CBM well, sample 4 (2,679.0-2,681.0 ft). .........................30
 

Table 10. Vitrinite reflectance data for CZ Fee A No. 114 CBM well, sample 7 (2,731.0-2,732.0 ft). .......................31
 

Table 11. Vitrinite reflectance data for CZ Fee A No. 114 CBM well, sample 11 (2,938.0-2,939.0 ft). .....................32
 

Table 12. Methane adsorption isotherm analytical data (as-analyzed basis) for CZ Fee A No. 114 CBM well, 

sample 4.....................................................................................................................................................................33
 

iii 
Table 13. Methane adsorption isotherm analytical data (dry basis) for CZ Fee A No. 114 CBM well, sample 4 .....34
 

Table 14. Methane adsorption isotherm analytical data (dry, ash-free basis) for CZ Fee A No. 114 CBM well, 

Table 15. Methane adsorption isotherm analytical data (as-analyzed basis) for CZ Fee A No. 114 CBM well, 

Table 17. Methane adsorption isotherm analytical data (dry, ash-free basis) for CZ Fee A No. 114 CBM well, 

Table 18. Methane adsorption isotherm analytical data (as-analyzed basis) for CZ Fee A No. 114 CBM well, 

Table 20. Methane adsorption isotherm analytical data (dry, ash-free basis) for CZ Fee A No. 114 CBM well, 

Table 22. Produced water data for CZ Fee A No. 114 well CBM well, March 2004..................................................43
 

sample 4 ....................................................................................................................................................................35
 

sample 7.....................................................................................................................................................................36
 

Table 16. Methane adsorption isotherm analytical data (dry basis) for CZ Fee A No. 114 CBM well, sample 7 .....37
 

sample 7 ....................................................................................................................................................................38
 

sample 11 ..................................................................................................................................................................39
 

Table 19. Methane adsorption isotherm analytical data (dry basis) for CZ Fee A No. 114 CBM well, sample 11 ...40
 

sample 11 ..................................................................................................................................................................41
 

Table 21. Produced water data for CZ Fee A No. 114 well CBM well, February 2004 .............................................42
 

Table 23. Gas-in-place (GIP) calculations for CZ Fee A No. 114 CBM well .............................................................44
 

APPENDIX 

Permission to publish coalbed methane analytical data from operator .....................................................................45
 

iv 
Results from coalbed methane drilling in 

Winn Parish, Louisiana 

By Paul C. Hackley, Peter D. Warwick, F. Clayton Breland, Jr., Troy E. Richard, 

and Kirk Ross 

INTRODUCTION 

A coalbed methane (CBM) well in Winn 

Parish, Louisiana, named CZ Fee A No. 

114, was drilled by Vintage Petroleum, Inc., 

in January 2004. The CZ Fee A No. 114 

CBM well was drilled to a total depth of 

3,114 ft and perforated at 2,730-2,734 ft in a 

Wilcox Group (Paleocene-Eocene) coal 

bed. Analytical data from the drilling project 

have been released by Vintage Petroleum, 

Inc., and by the current well operator, 

Hilcorp Energy Corporation (see Appendix) 

to the Louisiana Geological Survey (LGS) 

and the U.S. Geological Survey (USGS) for 

publication. General information about the 

CZ Fee A No. 114 CBM well is compiled in 

Table 1, and analytical data from the well 

are included in following sections. 

The CZ Fee A No. 114 well is located in 

eastern Winn Parish, approximately 30 mi 

east of where Wilcox Group strata crop out 

on the Sabine Uplift (fig. 1). In the CZ Fee 

A No. 114 well, lower Wilcox Paleocene 

coal beds targeted for CBM production 

occur at depths of 2,600-3,000 ft (fig. 2). 

Average monthly gas production for the 

reporting period August 1, 2004, through 

May 1, 2005, was 450 thousand cubic feet 

(Mcf) (Louisiana Department of Natural 

Resources, 2005). 

ANALYTICAL METHODS 

Coal and water samples obtained from 

the CZ Fee A No. 114 well were analyzed 

by contractors to Vintage Petroleum, Inc. 

Analytical methods used included canister 

gas desorption (Diamond and Levine, 1981; 

Diamond and others, 1986), proximate, 

heating value, and sulfur content analyses, 

organic petrographic analysis, and vitrinite 

reflectance (American Society for Testing of 

Materials, 2005), adsorption isotherm 

analysis (Mavor and others, 1990), and 

produced water quality analysis (Nelson, 

2003). 

COAL SAMPLES 

Thirteen coal samples were analyzed 

from three cored intervals in the Wilcox 

(Table 2). Samples 1 to 5 were recovered 

from core interval 1 (2,673.0 to 2,683.0 ft), 

samples 6 to 9 were recovered from core 

interval 2 (2,730.0 to 2,734.0 ft), and 

samples 10 to 13 were recovered from core 

interval 3 (2,937.0 to 2,941.0 ft) (fig. 2). 

GAS DESORPTION ANALYSES 

Results of canister desorption analyses 

of the 13 coal core samples are shown in 

Table 2. Ash yield versus bulk density and 

raw gas content versus bulk density are 

plotted in figs. 3 and 4, respectively. Gas 

content increases with depth and is 

inversely related to ash content and bulk 

density. Lost gas content was determined 

by the U.S. Bureau of Mines direct method 

(Diamond and Levine, 1981); plots for lost 

gas estimation and cumulative gas volume 

are shown for 8 samples in figs. 5 through 

12. Total gas content was in the range 6.04 

to 158.90 standard cubic feet per ton 

(scf/ton) (raw basis), or 91.88 to 213.49 

scf/ton on a dry, ash-free basis. Residual 

gas measurements (Diamond and others, 

1 
1986) were performed for four samples 

(Table 2) and determined to range 1.93 to 

5.56 scf/ton. Moisture content determined 

on the desorbed samples ranges from 8.45 

to 19.88 weight percent (wt.%) on an asreceived basis (as-rec’d) (Table 2); ash 

content determined on the desorbed 

samples ranges from 6.30 to 85.16 wt.% 

(as-rec’d) (Table 2). 

COAL QUALITY ANALYSES 

Proximate analyses, calorific value, and 

total sulfur content were determined for 

three coal samples (samples 4, 7, and 11), 

and are reported in Tables 3 through 5. 

Moisture content ranges from 12.13 to 18.65 

wt.% (as-rec’d). Proximate moisture values 

are similar to those reported by a different 

laboratory as part of the gas desorption 

analyses (1 to 2 wt.% absolute differences 

between the two sets of analyses; compare 

as-received moisture reported in Tables 3 

through 5 with Table 2). Ash yield ranges 

from 6.29 to 47.41 wt.% (as-rec’d). Ash 

yield is similar (~1 wt.% absolute 

differences) to that reported for the gas 

desorption analyses except for sample 4 

where the reported ash yield for the 

proximate analysis is 10 wt.% greater 

(absolute) than that reported in the gas 

desorption analysis (compare as-received 

ash yield in Table 3 with Table 2). Calorific 

value ranges from 10,046 to 10,904 British 

thermal units per pound (Btu/lb) on a moist, 

mineral-matter free basis and rank 

according to ASTM D 388 is subbituminous 

B-A. Sulfur content ranges from 0.56 to 

1.26 wt.% (as-rec’d). 

PETROGRAPHIC ANALYSES 

Maceral Analyses 

The results of petrographic analyses for 

samples 4, 7, and 11 are shown in Tables 6 

through 8. Samples contain 3.5 to 51.4 

volume percent (vol.%) mineral matter, 41.6 

to 60.5 vol.% vitrinite, 1.8 to 32.2 vol.% 

inertinite, and 2.9 to 5.2 vol.% liptinite 

(maceral composition on mineral-containing 

basis). Samples are dominated by 

detrovitrinite (47.8 to 69.8 vol.%; mineralfree basis), with subordinate telovitrinite. 

The high inertinite sample 11 (33.3 vol.% 

inertinite, mineral-free basis) comes from 

the deepest coal core (cored interval 3; 

2,937.0 to 2,941.0 ft). The high value for 

inertinite content in sample 11 is much 

higher than the range of inertinite values (2 

to 15 vol.%, mineral-free) reported by 

Hackley and Warwick (2005) for subsurface 

Wilcox coals located approximately 60 mi to 

the north in Ouachita Parish, Louisiana. 

Vitrinite Reflectance Analyses 

The results of measurements of the 

random reflectance of vitrinite for samples 4, 

7, and 11 are reported in Tables 9 through 

11. Values range between 0.34 and 39 % 

reflectance, indicating lignite to 

subbituminous C rank. Rank according to 

the reflectance of vitrinite is slightly lower 

than calculated by the Parr Formula (based 

on ASTM D 388). Reported values for the 

standard deviation of measured random 

reflectance are 0.05 to 0.075, indicating 

high levels of variability in the measured 

vitrinite populations. 

METHANE ADSORPTION ANALYSES 

Methane adsorption isotherm analyses 

were performed on samples 4, 7, and 11. 

Analytical data are included in Tables 12 to 

20 and isotherm plots are shown in figs. 13 

through 21. Comparison of desorbed gas 

content with methane adsorption isotherms 

indicate that the samples range from 

undersaturated to slightly oversaturated at 

hydrostatic reservoir pressure (fig. 22). 

Reservoir pressures for the cored intervals 

were estimated by multiplying depth by 

0.433 pounds per square inch per foot 

(psi/ft) (normal hydrostatic gradient; 

Schlumberger Limited, 2005). Equilibrium 

moisture values determined for the three 

samples as part of the isotherm analyses 

are 2 to 3.5 wt.% greater (absolute basis) 

than as-received moisture reported as part 

2 
of the desorption analyses, and 4 to 4.5 

wt.% greater than as-received proximate 

moisture. As-received ash yield determined 

as part of the isotherm analyses is within 2 

wt.% of ash yield reported for the proximate 

analyses. 

PRODUCED WATER ANALYSES 

Produced waters were collected in 

February and March, 2004. Water quality 

data are tabulated in Tables 21 and 22. 

Total dissolved solids ranged from 82,800 to 

84,600 milligrams per liter (mg/l); pH ranged 

from 5.85 to 6.58. 

GAS-IN-PLACE CALCULATIONS 

Calculated gas-in-place (GIP) for the 3 

cored intervals ranges from 144,515 to 

208,479 Mcf for 160 acre centers (Table 

23). Total GIP is 547,680 Mcf on 160 acre 

centers. The number of bulk density values 

(35) and their reported magnitude in Table 

23 is inconsistent with the number of bulk 

density values (13) reported for gas 

desorption analyses (Table 2) because 

cored intervals were sectioned into 0.5 ft 

sections and bulk density was estimated 

using the e-log. Ash fraction in Table 23 is 

calculated from the estimated bulk density; 

average gas content and moisture values 

used in the GIP calculations are from the 

gas desorption analyses (Table 2). 

ACKNOWLEDGEMENTS 

The USGS and LGS thank Vintage 

Petroleum, Inc., and Hilcorp Energy 

Corporation for sharing data on coalbed 

methane exploration in Winn Parish, LA. 

TerraTek Inc. and its contractors conducted 

the coal analyses; Baker Petrolite 

conducted the water analyses. Technical 

reviews by Leslie Ruppert and Alex Karlsen 

of USGS improved the quality and clarity of 

this report. 

REFERENCES CITED 

American Society for Testing and Materials 

(ASTM), 2005, Annual Book of ASTM 

Standards, Petroleum Products, 

Lubricants, and Fossil Fuels, Gaseous 

Fuels; Coal and Coke, Section 5, 

Volume 05.06: Philadelphia, PA, 

American Society for Testing and 

Materials, 675 pp. 

Diamond, W.P., LaScola, J.C., and Hyman, 

D.M., 1986, Results of direct method 

determination of the gas content of U.S. 

coalbeds: U.S. Bureau of Mines 

Information Circular 9067, 95 p. 

Diamond, W.P., and J.R. Levine, 1981, 

Direct method determination of the gas 

content of coal: procedures and results: 

U.S. Bureau of Mines Report of 

Investigations 8515, 36 p. 

Hackley, P.C., and Warwick, P.D., 2005, 

Organic petrography of coals from a 

coalbed methane test well, Ouachita 

Parish, Louisiana: U.S. Geological 

Survey Open-File Report 2005-1134, 22 

p., http://pubs.usgs.gov/of/2005/1134/. 

Louisiana Department of Natural 

Resources, 2005, SONRIS: Louisiana 

Department of Natural Resources 

website and database at http://sonriswww.dnr.state.la.us/www_root/sonris_

portal_1.htm (Accessed August, 2005). 

Mavor, M.J., Owen, L.B., and Pratt, T.J., 

1990, Measurement and evaluation of 

isotherm data: Proceedings of the 65th 

Annual Technical Conference and 

Exhibition of the Society of Petroleum 

Engineers, SPE 20728, New Orleans, 

Louisiana, p. 157-170. 

Nelson, P., 2003, Index to EPA Test 

Methods: U.S. Environmental Protection 

Agency Region 1 Library Publication, 85 

p., 

http://www.epa.gov/region01/info/testmet 

hods/pdfs/testmeth.pdf. 

Schlumberger Limited, 2005, Oilfield 

Glossary: Schlumberger Limited website 

at http://www.glossary.oilfield.slb.com/ 

(Accessed October, 2005). 

3 
Figure 1. Location of CZ Fee A No. 114 CBM well in Winn County, Louisiana. Heavy dashed 

line indicates depth to the top of the Wilcox Group. Light dashed line indicates outline of the 

Monroe Uplift. 

4 
Figure 2. E-logs and interpreted stratigraphy of CZ Fee A No. 114 CBM well. 

5 
Figure 3. Ash yield (as-received) versus bulk density, CZ Fee A No. 114 CBM well samples. 

Abbreviations: % = percent; as-rec’d = as-received; g/cc = grams per cubic centimeter. 

6 
Figure 4. Raw gas content versus bulk density, CZ Fee A No. 114 CBM well samples. 

Abbreviations: scf/ton = standard cubic feet per ton; g/cc = grams per cubic centimeter. 

7 
Figure 5. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM 

well, sample 1. Abbreviations: sl = standard liter; scf/ton = standard cubic foot per ton; hrs = 

hours. Desorbed gas volume on abscissa ranges 0.00-0.40 sl. 

8 
Figure 6. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM 

well, sample 2. Abbreviations: sl = standard liter; scf/ton = standard cubic foot per ton; hrs = 

hours. Desorbed gas volume on abscissa ranges 0.00-2.00 sl. 

9 
Figure 7. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM 

well, sample 3. Abbreviations: sl = standard liter; scf/ton = standard cubic foot per ton; hrs = 

hours. Desorbed gas volume on abscissa ranges 0.00-1.60 sl. 

10 
Figure 8. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM 

well, sample 9. Abbreviations: sl = standard liter; scf/ton = standard cubic foot per ton; hrs = 

hours. Desorbed gas volume on abscissa ranges 0.00-2.00 sl. 

11 
Figure 9. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM 

well, sample 10. Abbreviations: sl = standard liter; scf/ton = standard cubic foot per ton; hrs = 

hours. Desorbed gas volume on abscissa ranges 0.00-2.50 sl. 

12 
Figure 10. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM 

well, sample 11. Abbreviations: sl = standard liter; scf/ton = standard cubic foot per ton; hrs = 

hours. Desorbed gas volume on abscissa ranges 0.00-2.50 sl. 

13 
Figure 11. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM 

well, sample 12. Abbreviations: sl = standard liter; scf/ton = standard cubic foot per ton; hrs = 

hours. Desorbed gas volume on abscissa ranges 0.00-3.00 sl. 

14 
Figure 12. A. Lost gas estimation, and B. Cumulative gas volume for CZ Fee A No. 114 CBM 

well, sample 13. Abbreviations: sl = standard liter; scf/ton = standard cubic foot per ton; hrs = 

hours. Desorbed gas volume on abscissa ranges 0.00-1.60 sl. 

15 
Figure 13. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 4, raw basis. 

Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard cubic feet per 

ton; psi = pounds per square inch. 

Figure 14. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 4, dry basis. 

Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard cubic feet per 

ton; psi = pounds per square inch. 

16 
Figure 15. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 4, dry, ash-free 

basis. Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard cubic 

feet per ton; psi = pounds per square inch. 

Figure 16. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 7, raw basis. 

Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard cubic feet per 

ton; psi = pounds per square inch. 

17 
Figure 17. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 7, dry basis. 

Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard cubic feet per 

ton; psi = pounds per square inch. 

Figure 18. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 7, dry, ash-free 

basis. Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard cubic 

feet per ton; psi = pounds per square inch. 

18 
Figure 19. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 11, raw-basis. 

Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard cubic feet per 

ton; psi = pounds per square inch. 

Figure 20. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 11, dry basis. 

Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard cubic feet per 

ton; psi = pounds per square inch. 

19 
Figure 21. Methane adsorption isotherm, CZ Fee A No. 114 CBM well, sample 11, dry, ashfree basis. Abbreviations: EQ. = equilibrium; V = volume; P = pressure; scf/ton = standard 

cubic feet per ton; psi = pounds per square inch. 

20 
Figure 22. Methane adsorption isotherms and measured gas content, CZ Fee A No. 114 CBM 

well, as-analyzed basis. Abbreviations: scf/ton = standard cubic feet per ton; psi = pounds per 

square inch. 

21 
 

 

 

 

 

 

 

 

 

 

Table 1. General information for CZ Fee A No. 114 CBM well, Winn Parish, LA. 

Hole name: CZ Fee A No. 114 

API number: 17127223830000 

Louisiana serial number: 

228951 

Spud Date: 1/8/2004 

Completion Date: 4/12/2004 

Operator: Vintage Petroleum, 

Inc. 

Parish: Winn 

Latitude: 31o54’28” 

Longitude: 92o29’19” 

Township, Range, Section: 11N, 01W, 

029 

Perforation Interval: 2,730-2,734 

ft 

Total depth of hole: 

3,114 ft 

Cored Intervals: 2,673-2,683 ft, 2,730-2,734 ft, 2,937-2,941 ft, all in Wilcox Group (PaleoceneEocene). 

22 
Table 2. Gas desorption data for CZ Fee A No. 114 

CBM well. 

TOTAL USBM TOTAL MOISTURE AS

SAMPLE MEASURED USBM USBM 

TOTAL 

GAS (scf/ton) BULK CONTENT CON

CORE SAMPLE DEPTH WEIGHT GAS LOST GAS GAS RAW DAF DENSITY (wt.%, (wt

(ft) (g) (scc) (scc) (scc) DATA BASIS (g/cc) as-rec'd) as-re

1 2,673.0-75.0 2,399.1 348 104 452 6.04 109.82 2.277 9.34 85.

2 2,675.0-77.0 1,802.3 1,763 589 2,352 41.81 140.11 1.771 14.02 56.

1 3 2,677.0-79.0 2,444.2 1,455 291 1,746 22.89 192.84 2.158 10.16 77.

4 2,679.0-81.0 1,540.3 2,802 1,239 4,041 84.05 142.36 1.529 15.98 24.

5 2,681.0-83.0 2,428.8 381 408 789 10.41 91.88 2.180 8.45 80.6 2,730.0-31.0 1,040.3 1,096 501 1,597 49.19 150.29 1.749 14.13 53.

2 7 2,731.0-32.0 985.8 1,335 651 1,986 64.55 168.27 1.681 13.00 48.

8 2,732.0-33.0 982.4 961 616 1,577 51.44 154.47 1.700 13.81 52.

9 2,733.0-34.0 494.0 1,785 665 2,450 158.90 213.49 1.290 18.50 7.0

10 2,937.0-38.0 765.5 2,170 619 2,789 116.73 167.69 1.321 18.77 11.

3 11 2,938.0-39.0 736.0 1,974 646 2,620 114.03 154.47 1.314 19.88 6.3

12 2,939.0-40.0 756.6 2,715 723 3,438 145.59 193.06 1.286 18.28 6.3

13 2,940.0-41.0 889.4 1,516 557 2,073 74.66 230.29 1.709 12.01 55.

Abbreviations: ft = feet, g = grams, scc = standard cubic centimeters, scf/ton = standard cubic feet per ton, g/cc = grams per cubic centimeter, wt.% = w

dry, ash-free, USBM = U.S. Bureau of Mines (Diamond and Levine, 1981). 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 3. Coal quality data for CZ Fee A No. 114 CBM well, sample 4 (2,679.0-2,681.0 ft). 

As- Moisture- Moisture 

ANALYSIS Received Free & Ash-Free 

(wt. %) (wt. %) (wt. %) 

PROXIMATE ANALYSIS 

 Moisture 13.88

 Ash 35.25 40.93

 Volatile Matter 26.02 30.21 51.15 

Fixed Carbon 24.85 28.86 48.85 

Total 100.00 100.00 100.00 

HEATING VALUE (Btu/lb) 6,624 7,692 13,021 

SULFUR 0.99 1.15 1.95 

COAL RANKING DATA -- BASED ON PARR FORMULAS (ASTM D 

388) 

 Dry, Mm-free FC 52.00

 Dry, Mm-free VM 48.00 

Moist, Mm-free Btu 10,710 

Agglomerating Characteristics Not Determined

Sub Bituminous 

 Coal Rank A 

Abbreviations: ft = feet, wt.% = weight percent, Btu/lb = British thermal units per pound, FC = fixed carbon, 

VM = volatile matter, Mm = mineral matter, ASTM = American Society for Testing and Materials (ASTM, 

2005). 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 4. Coal quality data for CZ Fee A No. 114 CBM well, sample 7 (2,731.0-2,732.0 ft). 

As- Moisture- Moisture 

ANALYSIS Received Free & Ash-Free 

(wt. %) (wt. %) (wt. %) 

PROXIMATE ANALYSIS 

 Moisture 12.13

 Ash 47.41 53.95

 Volatile Matter 22.99 26.16 56.82 

Fixed Carbon 17.47 19.88 43.18 

Total 100.00 100.00 100.00 

HEATING VALUE (Btu/lb) 4,899 5,575 12,108 

SULFUR 0.56 0.64 1.38 

COAL RANKING DATA -- BASED ON PARR FORMULAS (ASTM D 

388) 

 Dry, Mm-free FC 47.82

 Dry, Mm-free VM 52.18 

Moist, Mm-free Btu 10,046 

Agglomerating Characteristics Not Determined

Sub Bituminous 

 Coal Rank B 

Abbreviations: ft = feet, wt.% = weight percent, Btu/lb = British thermal units per pound, FC = fixed carbon, 

VM = volatile matter, Mm = mineral matter, ASTM = American Society for Testing and Materials (ASTM, 

2005). 

25 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 5. Coal quality data for CZ Fee A No. 114 CBM well, sample 11 (2,938.0-2,939.0 

ft). 

As- Moisture- Moisture 

ANALYSIS Received Free & Ash-Free 

(wt. %) (wt. %) (wt. %) 

PROXIMATE ANALYSIS 

 Moisture 18.65

 Ash 6.29 7.73

 Volatile Matter 33.21 40.82 44.24 

Fixed Carbon 41.85 51.44 55.76 

Total 100.00 100.00 100.00 

HEATING VALUE (Btu/lb) 10,151 12,478 13,524 

SULFUR 1.26 1.55 1.68 

COAL RANKING DATA -- BASED ON PARR FORMULAS (ASTM D 

388) 

Dry, Mm-free FC (wt.%) 56.40 

Dry, Mm-free VM (wt.%) 43.60 

Moist, Mm-free Btu/lb 10,904 

Agglomerating Characteristics Not Determined

Sub Bituminous 

 Coal Rank A 

Abbreviations: ft = feet, wt.% = weight percent, Btu/lb = British thermal units per pound, FC = fixed carbon, 

VM = volatile matter, Mm = mineral matter, ASTM = American Society for Testing and Materials (ASTM, 

2005). 

26 
 

 

 

 

 

Table 6. Petrographic data for CZ Fee A No. 114 CBM well, 

sample 4 (2,679.0-2,681.0 ft). 

Maceral % with Maceral % without 

Maceral Type Counts Mineral Matter Mineral Matter 

Detrovitrinite 344 34.57% 69.49% 

Telovitrinite 78 7.84% 15.76% 

Total Vitrinite 42.41% 85.25% 

Sporinite 11 1.11% 2.22% 

Cutinite 7 0.70% 1.41% 

Resinite 11 1.11% 2.22% 

Exsudanite 

(bitumen) 0.00% 0.00% 

Total Liptinite 2.91% 5.86% 

Detroinertinite 25 2.51% 5.05% 

Fusinite 5 0.50% 1.01% 

Semifusinite 7 0.70% 1.41% 

Macrinite 6 0.60% 1.21% 

Funginite 1 0.10% 0.20% 

Total Inertinite 4.42% 8.89% 

clay/other 500 50.25% 

quartz 0.00% 

carbonate 0.00% 

pyrite 0.00% 

Total Minerals 50.25% 

Total Sum 995 100.00% 100.00% 

27 
 

Table 7. Petrographic data for CZ Fee A No. 114 CBM well, 

sample 7 (2,731.0-2,732.0 ft). 

Maceral % with Maceral % without 

Maceral Type Counts Mineral Matter Mineral Matter 

Detrovitrinite 330 33.92% 69.77% 

Telovitrinite 75 7.71% 15.86% 

Total Vitrinite 41.62% 85.62% 

Sporinite 8 0.82% 1.69% 

Cutinite 1 0.10% 0.21% 

Resinite 42 4.32% 8.88% 

Exsudanite 

(bitumen) 0 0.00% 0.00% 

Total Liptinite 5.24% 10.78% 

Detroinertinite 11 1.13% 2.33% 

Fusinite 1 0.10% 0.21% 

Semifusinite 1 0.10% 0.21% 

Macrinite 4 0.41% 0.85% 

Funginite 0 0.00% 0.00% 

Total Inertinite 1.75% 3.59% 

clay/other 500 51.39% 

quartz 0 0.00% 

carbonate 0 0.00% 

pyrite 0 0.00% 

Total Minerals 51.39% 

Total Sum 973 100.00% 100.00% 

28 
 

Table 8. Petrographic data for CZ Fee A No. 114 CBM well, 

sample 11 (2,938.0-2,939.0 ft). 

Maceral % with Maceral % without 

Maceral Type Counts Mineral Matter Mineral Matter 

Detrovitrinite 251 46.14% 47.81% 

Telovitrinite 78 14.34% 14.86% 

Total Vitrinite 60.48% 62.67% 

Sporinite 15 2.76% 2.86% 

Cutinite 2 0.37% 0.38% 

Resinite 4 0.74% 0.76% 

Exsudanite 

(bitumen) 0 0.00% 0.00% 

Total Liptinite 3.86% 4.00% 

Detroinertinite 104 19.12% 19.81% 

Fusinite 23 4.23% 4.38% 

Semifusinite 33 6.07% 6.29% 

Macrinite 15 2.76% 2.86% 

Funginite 0 0.00% 0.00% 

Total Inertinite 32.17% 33.33% 

clay/other 17 3.13% 

quartz 2 0.37% 

carbonate 0 0.00% 

pyrite 0 0.00% 

Total Minerals 3.49% 

Total Sum 544 100.00% 100.00% 

29 
 

 

 

 

Table 9. Vitrinite reflectance data for CZ Fee A No. 114 CBM well, 

sample 4 (2,679.0-2,681.0 ft). 

Readings 

0.26 0.28 0.28 0.29 0.30 0.31 

0.33 0.34 0.34 0.34 0.35 0.35 

0.37 0.38 0.38 0.38 0.38 0.38 

0.40 0.41 0.41 0.42 0.42 0.42 

0.44 0.45 0.45 0.47 0.67 0.68 

0.32 0.32 0.32 0.33 0.33 0.33 

0.35 0.35 0.35 0.35 0.36 0.36 

0.38 0.38 0.39 0.39 0.39 0.40 

0.42 0.43 0.43 0.43 0.43 0.43 

Total Minimum Maximum Mean Standard 

Readings Reflectance Reflectance Reflectance Deviation Coal Rank 

Subbituminous 

54 0.26 % 0.68 % 0.38 % 0.075 % C 

30 
 

 

 

Table 10. Vitrinite reflectance data for CZ Fee A No. 114 CBM well, 

sample 7 (2,731.0-2,732.0 ft). 

Readings 

0.26 0.27 0.29 0.31 0.32 0.33 

0.35 0.36 0.36 0.36 0.37 0.37 

0.39 0.39 0.39 0.39 0.39 0.39 

0.41 0.42 0.42 0.42 0.42 0.42 

0.46 0.46 0.46 0.48 0.49 0.55 

0.33 0.33 0.33 0.34 0.34 0.35 

0.38 0.38 0.38 0.38 0.38 0.39 

0.39 0.40 0.40 0.40 0.40 0.41 

0.43 0.43 0.44 0.44 0.44 0.46 

Total Minimum Maximum Mean Standard 

Readings Reflectance Reflectance Reflectance Deviation Coal Rank 

Subbituminous 

54 0.26 % 0.55 % 0.39 % 0.05 % C 

31 
 

 

 

 

Table 11. Vitrinite reflectance data for CZ Fee A No. 114 CBM 

well, sample 11 (2,938.0-2,939.0 ft). 

Readings 

0.26 0.27 0.28 0.28 0.29 0.29 

0.30 0.31 0.31 0.31 0.31 0.32 

0.33 0.33 0.33 0.34 0.34 0.34 

0.36 0.37 0.37 0.37 0.38 0.38 

0.43 0.45 0.47 0.50 0.30 0.30 

0.29 0.29 0.29 0.29 0.33 0.33 

0.32 0.32 0.33 0.33 0.36 0.36 

0.35 0.35 0.35 0.36 0.41 0.41 

0.39 0.39 0.40 0.40 

Total Minimum Maximum Mean Standard Coal 

Readings Reflectance Reflectance Reflectance Deviation Rank 

52 0.26 % 0.5 % 0.34 % 0.05 % Lignite 

32 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 12. Methane adsorption isotherm analytical data (as-analyzed basis) for CZ Fee A 

No. 114 CBM well, sample 4 (2,679.0-2,681.0 ft). Abbreviations: g = grams; % = percent; 

oF = degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; MPa = 

Mega Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic centimeters 

per gram; V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 4 Depth: 2,679.0'-81.0' 

As-Analyzed Basis 

Sample Weight = 131.36 g Ash Content = 33.30 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 18.55% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

 Pressure 

 (psi) (MPa) 

Gas Content (Raw Basis)

(scf/ton) (scc/gm) 

52 

117 

215 

354 

544 

833 

1,232 

1,655 

2,151 

0.36 

0.81 

1.48 

2.44 

3.75 

5.74 

8.49 

11.41 

14.83 

7.7 

15.8 

26.9 

40.7 

55.2 

71.4 

88.1 

98.9 

109.2 

0.24 

0.49 

0.84 

1.27 

1.72 

2.23 

2.75 

3.09 

3.41 

Langmuir Coefficients V = 164.4 * P / (P + 1,085.0) 

PL 

 (psi) (MPa) 

VL (Raw Basis)

(scf/ton) (scc/gm) 

1,085.0 7.48 164.4 5.1 

33 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 13. Methane adsorption isotherm analytical data (dry basis) for CZ Fee A No. 114 

CBM well, sample 4 (2,679.0-2,681.0 ft). Abbreviations: g = grams; % = percent; oF = 

degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; MPa = Mega 

Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic centimeters per gram; 

V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 4 Depth: 2,679.0'-81.0' 

Dry Basis 

Sample Weight = 131.36 g Ash Content = 33.30 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 18.55% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

Pressure 

(psi) (MPa) 

Gas Content (Dry Basis) 

(scf/ton) (scc/gm) 

52 

117 

215 

354 

544 

833 

1,232 

1,655 

2,151 

0.36 

0.81 

1.48 

2.44 

3.75 

5.74 

8.49 

11.41 

14.83 

9.4 

19.4 

33.0 

50.0 

67.8 

87.7 

108.2 

121.4 

134.1 

0.29 

0.61 

1.03 

1.56 

2.12 

2.74 

3.38 

3.79 

4.19 

Langmuir Coefficients V = 201.9 * P / (P + 1,085.0) 

PL 

(psi) (MPa) 

VL (Dry Basis) 

(scf/ton) (scc/gm) 

1,085.0 7.48 201.9 6.3 

34 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 14. Methane adsorption isotherm analytical data (dry, ash-free basis) for CZ Fee A 

No. 114 CBM well, sample 4 (2,679.0-2,681.0 ft). Abbreviations: g = grams; % = percent; oF 

= degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; MPa = Mega 

Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic centimeters per gram; 

V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 4 Depth: 2,679.0'-81.0' 

Dry, Ash-Free Basis 

Sample Weight = 131.36 g Ash Content = 33.30 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 18.55% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

Pressure 

(psi) (MPa) 

Gas Content (Dry, Ash-Free Basis) 

(scf/ton) (scc/gm) 

52 

117 

215 

354 

544 

833 

1,232 

1,655 

2,151 

0.36 

0.81 

1.48 

2.44 

3.75 

5.74 

8.49 

11.41 

14.83 

15.9 0.50 

32.8 1.02 

55.8 1.74 

84.6 2.64 

114.7 3.58 

148.3 4.63 

183.0 5.71 

205.3 6.41 

226.8 7.08 

Langmuir Coefficients V = 341.5 * P / (P + 1,085.0) 

PL 

(psi) (MPa) 

VL (Dry, Ash-Free Basis) 

(scf/ton) (scc/gm) 

1,085.0 7.48 341.5 10.6 

35 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 15. Methane adsorption isotherm analytical data (as-analyzed basis) for CZ Fee A 

No. 114 CBM well, sample 7 (2,731.0-2,732.0 ft). Abbreviations: g = grams; % = percent; 

oF = degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; MPa = 

Mega Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic centimeters 

per gram; V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 7 Depth: 2,731.0'-32.0' 

As-Analyzed Basis 

Sample Weight = 134.03 g Ash Content = 46.99 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 16.20% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

 Pressure 

 (psi) (MPa) 

Gas Content (Raw Basis)

(scf/ton) (scc/gm) 

62 

115 

212 

359 

536 

821 

1,211 

1,630 

2,130 

0.43 

0.79 

1.46 

2.48 

3.70 

5.66 

8.35 

11.24 

14.69 

5.7 

10.6 

18.5 

28.4 

38.5 

49.4 

61.6 

70.4 

77.4 

0.18 

0.33 

0.58 

0.89 

1.20 

1.54 

1.92 

2.20 

2.42 

Langmuir Coefficients V = 122.0 * P / (P + 1,202.5) 

PL 

 (psi) (MPa) 

VL (Raw Basis)

(scf/ton) (scc/gm) 

1,202.5 8.29 122.0 3.8 

36 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 16. Methane adsorption isotherm analytical data (dry basis) for CZ Fee A No. 114 

CBM well, sample 7 (2,731.0-2,732.0 ft). Abbreviations: g = grams; % = percent; oF = 

degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; MPa = Mega 

Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic centimeters per 

gram; V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 7 Depth: 2,731.0'-32.0' 

Dry Basis 

Sample Weight = 134.03 g Ash Content = 46.99 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 16.20% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

 Pressure 

 (psi) (MPa) 

Gas Content (Dry Basis)

(scf/ton) (scc/gm) 

62 

115 

212 

359 

536 

821 

1,211 

1,630 

2,130 

0.43 

0.79 

1.46 

2.48 

3.70 

5.66 

8.35 

11.24 

14.69 

6.8 

12.6 

22.1 

33.9 

46.0 

58.9 

73.5 

84.0 

92.4 

0.21 

0.39 

0.69 

1.06 

1.44 

1.84 

2.29 

2.62 

2.88 

Langmuir Coefficients V = 145.6 * P / (P + 1,202.5) 

PL 

 (psi) (MPa) 

VL (Dry Basis)

(scf/ton) (scc/gm) 

1,202.5 8.29 145.6 4.5 

37 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 17. Methane adsorption isotherm analytical data (dry, ash-free basis) for CZ Fee A 

No. 114 CBM well, sample 7 (2,731.0-2,732.0 ft). Abbreviations: g = grams; % = percent; 

oF = degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; MPa = 

Mega Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic centimeters 

per gram; V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 7 Depth: 2,731.0'-32.0' 

Dry, Ash-Free Basis 

Sample Weight = 134.03 g Ash Content = 46.99 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 16.20% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

Pressure 

(psi) (MPa) 

Gas Content (Dry, Ash-Free Basis) 

(scf/ton) (scc/gm) 

62 

115 

212 

359 

536 

821 

1,211 

1,630 

2,130 

0.43 

0.79 

1.46 

2.48 

3.70 

5.66 

8.35 

11.24 

14.69 

15.5 0.48 

28.7 0.90 

50.3 1.57 

77.2 2.41 

104.7 3.27 

134.1 4.19 

167.3 5.22 

191.2 5.97 

210.3 6.56 

Langmuir Coefficients V = 331.4 * P / (P + 1,202.5) 

PL 

(psi) (MPa) 

VL (Dry, Ash-Free Basis) 

(scf/ton) (scc/gm) 

1,202.5 8.29 331.4 10.3 

38 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 18. Methane adsorption isotherm analytical data (as-analyzed basis) for CZ Fee A 

No. 114 CBM well, sample 11 (2,938.0-2,939.0 ft). Abbreviations: g = grams; % = 

percent; oF = degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; 

MPa = Mega Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic 

centimeters per gram; V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 11 Depth: 2,938.0'-39.0' 

As-Analyzed Basis 

Sample Weight = 87.03 g Ash Content = 6.46 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 23.42% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

 Pressure 

 (psi) (MPa) 

Gas Content (Raw Basis)

(scf/ton) (scc/gm) 

58 

110 

202 

343 

517 

792 

1,173 

1,581 

2,070 

0.40 

0.76 

1.39 

2.36 

3.56 

5.46 

8.09 

10.90 

14.27 

10.8 

21.1 

36.9 

57.5 

71.8 

96.5 

118.9 

137.2 

150.4 

0.34 

0.66 

1.15 

1.79 

2.24 

3.01 

3.71 

4.28 

4.69 

Langmuir Coefficients V = 231.9 * P / (P + 1,109.1) 

PL 

 (psi) (MPa) 

VL (Raw Basis)

(scf/ton) (scc/gm) 

1,109.1 7.65 231.9 7.2 

39 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 19. Methane adsorption isotherm analytical data (dry basis) for CZ Fee A No. 114 

CBM well, sample 11 (2,938.0-2,939.0 ft). Abbreviations: g = grams; % = percent; oF = 

degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; MPa = Mega 

Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic centimeters per 

gram; V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 11 Depth: 2,938.0'-39.0' 

Dry Basis 

Sample Weight = 87.03 g Ash Content = 6.46 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 23.42% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

Pressure 

(psi) (MPa) 

Gas Content (Dry Basis) 

(scf/ton) (scc/gm) 

58 

110 

202 

343 

517 

792 

1,173 

1,581 

2,070 

0.40 

0.76 

1.39 

2.36 

3.56 

5.46 

8.09 

10.90 

14.27 

14.1 

27.5 

48.2 

75.1 

93.8 

126.0 

155.3 

179.1 

196.4 

0.44 

0.86 

1.50 

2.34 

2.93 

3.93 

4.85 

5.59 

6.13 

Langmuir Coefficients V = 302.8 * P / (P + 1,109.1) 

PL 

(psi) (MPa) 

VL (Dry Basis) 

(scf/ton) (scc/gm) 

1,109.1 7.65 302.8 9.4 

40 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 20. Methane adsorption isotherm analytical data (dry, ash-free basis) for CZ Fee 

A No. 114 CBM well, sample 11 (2,938.0-2,939.0 ft). Abbreviations: g = grams; % = 

percent; oF = degrees Fahrenheit; oC = degrees Celsius; psi = pounds per square inch; 

MPa = Mega Pascal; scf/ton = standard cubic feet per ton; scc/gm = standard cubic 

centimeters per gram; V = volume; P = pressure. 

Methane Adsorption Isotherm 

Vintage Petroleum Well: CZ Fee A No. 114 

Sample: 11 Depth: 2,938.0'-39.0' 

Dry, Ash-Free Basis 

Sample Weight = 87.03 g Ash Content = 6.46 % 

Particle Size = < 20 Mesh Equilibrium Moisture Content = 23.42% 

Temperature = 110.0oF (43.3oC) 

Methane Adsorption 

Pressure 

(psi) (MPa) 

Gas Content (Dry, Ash-Free Basis) 

(scf/ton) (scc/gm) 

58 

110 

202 

343 

517 

792 

1,173 

1,581 

2,070 

0.40 

0.76 

1.39 

2.36 

3.56 

5.46 

8.09 

10.90 

14.27 

15.4 0.48 

30.0 0.94 

52.6 1.64 

82.0 2.56 

102.4 3.20 

137.6 4.30 

169.6 5.29 

195.6 6.11 

214.5 6.70 

Langmuir Coefficients V = 330.7 * P / (P + 1,109.1) 

PL 

(psi) (MPa) 

VL (Dry, Ash-Free Basis) 

(scf/ton) (scc/gm) 

1,109.1 7.65 330.7 10.3 

41 
 

 

 

 

 

 

 

 

 

 

Table 21. Produced water data for CZ Fee A No. 114 CBM 

well, February 2004. Abbreviations: TDS = total dissolved 

solids; mg/l = milligrams per liter; g/cm3 = grams per cubic 

centimeter; oF = degrees Fahrenheit; meq/l = milliequivalents 

per liter. 

Summary 

Sampling Date 25-Feb04 

Analysis Date 4-Mar04 

TDS (mg/l) 82,819.6 

Density (g/cm3

) 1.061 

Anion/Cation 1.00 

Ratio 

Anions (75o F) mg/l meq/l 

Chloride 50,100 1,413 

Bicarbonate 226 3.70 

Sulfate 44.8 0.93 

pH at time of sampling 5.85 

pH at time of analysis 5.85 

pH used in calculations 5.85 

Cations (75o F) mg/l meq/l 

Sodium 29,133 1,267 

Magnesium 171 14.1 

Calcium 2,520 126 

Barium 549 8.00 

Iron 75.3 2.70 

Manganese 0.96 0.03 

42 
 

 

 

 

 

 

 

Table 22. Produced water data for CZ Fee A No. 114 CBM 

well, March 2004. Abbreviations: TDS = total dissolved solids; 

mg/l = milligrams per liter; g/cm3 = grams per cubic centimeter; 

oF = degrees Fahrenheit; meq/l = milliequivalents per liter. 

Summary 

Sampling Date 25-Mar04 

Analysis Date 6-Apr-04 

TDS (mg/l) 

Density (g/cm3

) 

84,598.4 

1.063 

Anion/Cation 1.00 

Ratio 

Anions (75o F) mg/l meq/l 

Chloride 51,100 1,441 

Bicarbonate 372 6.10 

Sulfate 0.39 0.01 

pH at time of sampling 6.58 

pH at time of analysis 6.58 

pH used in calculations 6.58 

Cations (75o F) mg/l meq/l 

Sodium 29,696 1,292 

Magnesium 97.6 8.03 

Calcium 2,800 140 

Barium 521 7.59 

Iron 10.9 0.39 

Manganese 0.34 0.01 

43 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Table 23. Gas-in-place (GIP) calculations for CZ Fee A No. 114 CBM well. 

Assumptions: 

Drainage 160 Acres 

Core #1 

Depth (ft) Cgi (scf/ton) ρc (g/cm3

) fa fm A (acres) h (ft) GIP (Mcf) 

2,672 135.4 1.65 0.403 0.116 160 0.5 11,690 

2,672.5 135.4 1.35 0.155 0.116 160 0.5 14,481 

2,673 135.4 1.3 0.114 0.116 160 0.5 14,734 

2,673.5 135.4 1.25 0.073 0.116 160 0.5 14,926 

2,674 135.4 1.26 0.081 0.116 160 0.5 14,892 

2,674.5 135.4 1.27 0.089 0.116 160 0.5 14,856 

2,675 135.4 1.3 0.114 0.116 160 0.5 14,734 

2,675.5 135.4 1.27 0.089 0.116 160 0.5 14,856 

2,676 135.4 1.45 0.238 0.116 160 0.5 13,793 

2,679 135.4 1.7 0.444 0.116 160 0.5 11,012 

2,679.5 135.4 1.4 0.197 0.116 160 0.5 14,167 

2,680 135.4 1.33 0.139 0.116 160 0.5 14,589 

2,680.5 135.4 1.32 0.131 0.116 160 0.5 14,640 

2,681 135.4 1.41 0.205 0.116 160 0.5 14,097 

2,681.5 135.4 1.7 0.444 0.116 160 0.5 11,012 

Total core 1 208,479 

Core #2 

Depth (ft) Cgi (scf/ton) ρc (g/cm3

) fa fm A (acres) h (ft) GIP (Mcf) 

2,730 171.6 1.55 0.320 0.148 160 0.5 15,376 

2,730.5 171.6 1.57 0.337 0.148 160 0.5 15,092 

2,731 171.6 1.41 0.205 0.148 160 0.5 17,025 

2,731.5 171.6 1.29 0.106 0.148 160 0.5 17,958 

2,732 171.6 1.25 0.073 0.148 160 0.5 18,170 

2,732.5 171.6 1.3 0.114 0.148 160 0.5 17,897 

2,733 171.6 1.32 0.131 0.148 160 0.5 17,766 

2,733.5 171.6 1.45 0.238 0.148 160 0.5 16,615 

2,734 171.6 1.9 0.609 0.148 160 0.5 8,617 

Total core 2 144,515 

Core #3 

Depth (ft) Cgi (scf/ton) ρc (g/cm3

) fa fm A (acres) h (ft) GIP (Mcf) 

2,938 186.4 1.78 0.510 0.1723 160 0.5 14,462 

2,938.5 186.4 1.38 0.180 0.1723 160 0.5 18,112 

2,939 186.4 1.3 0.114 0.1723 160 0.5 18,800 

2,939.5 186.4 1.35 0.155 0.1723 160 0.5 18,395 

2,940 186.4 1.3 0.114 0.1723 160 0.5 18,800 

2,940.5 186.4 1.3 0.114 0.1723 160 0.5 18,800 

2,941 186.4 1.3 0.114 0.1723 160 0.5 18,800 

2,941.5 186.4 1.3 0.114 0.1723 160 0.5 18,800 

2,942 186.4 1.3 0.114 0.1723 160 0.5 18,800 

2,942.5 186.4 1.3 0.114 0.1723 160 0.5 18,800 

2,943 186.4 1.6 0.362 0.1723 160 0.5 15,116 

Total core 3 194,686 

547,680 

GIP Total of all 3 seams Mcf 

Explanation: Depth = top of 0.5 ft sample interval, Cgi = average measured desorbed gas content for entire cored interval (see Table 2), 

dry ash-free, ρc = bulk density, fa = ash fraction of 0.5 ft sample interval (calculated from bulk density), fm = moisture fraction of 0.5 ft 

interval, A = area, h = height, GIP = gas in place = A·h·[1.359·Cgi·ρc·(1-fa-fm)]. Abbreviations: scf/ton = standard cubic feet per ton; g/cm3 

= grams per cubic centimeter; ft = feet; Mcf = thousand cubic feet 

44 
 

 

 

 

 

APPENDIX: Permission to publish coalbed methane analytical data from operator 

"Troy Richard" 

<trichard@hilcorp.com> To "Paul C Hackley" <phackley@usgs.gov> 

06/26/2007 08:42 AM cc
 

Subjec RE: Release of Colgrade CZ "A" #114 cbm data 

t 

Mr. Hackley, 

On May 9, 2007, I obtain approval from Hilcorp’s Executive Vice President – Exploitation. You have Hilcorp’s 

permission to publish the information as written. 

Troy E. Richard, CPL 

Senior Landman 

Hilcorp Energy Company, General Partner 

For Hilcorp Energy I, L.P. 

(713) 289-2651 Phone 

(713) 209-2420 Fax 

45