Results of coalbed-methane drilling, Mylan Park, Monongalia County, West Virginia
<p>The Department of Energy National Energy Technology Laboratory funded drilling of a borehole (39.64378°N., 80.04376°W.) to evaluate the potential…
Public-domain full text preserved in the Mountain Man Mining Library. Original source: pubs.usgs.gov.
Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia By Leslie F. Ruppert, Nick Fedorko, Peter D. Warwick, William C. Grady, James Q. Britton, William A. Schuller, and Robert D. Crangle, Jr. Chapter G.3 of Coal and Petroleum Resources in the Appalachian Basin: Distribution, Geologic Framework, and Geochemical Character Edited by Leslie F. Ruppert and Robert T. Ryder Professional Paper 1708 U.S. Department of the Interior U.S. Geological Survey
Suggested citation: Ruppert, L.F., Fedorko, Nick, Warwick, P.D., Grady, W.C., Britton, J.Q., Schuller, W.A., and Crangle, R.D., Jr., 2014, Results of coalbed-methane drilling, Mylan Park, Monongalia County, West Virginia, chap. G.3 of Ruppert, L.F., and Ryder, R.T., eds., Coal and petroleum resources in the Appalachian basin; Distribution, geologic framework, and geochemical character: U.S. Geological Survey Professional Paper 1708, 33 p., http://dx.doi.org/10.3133/pp1708G.3.
Figures
1. Generalized location map of the Mylan Park study area in Monongalia County, W. Va 2
2. Generalized stratigraphic column showing Pennsylvanian coal beds and coal zones from which samples were desorbed for coalbed-methane content in the Mylan Park study area, Monongalia County, W. Va 3 3.-15. Graphs showing cumulative coal-bed-gas desorption volumes of the coal samples plotted against the square root of time for the—
3. Sewickley coal bed 15
4. Redstone coal bed 16
5. Pittsburgh roof coal interval 17
6. Pittsburgh coal bed 18 Contents Abstract 1 Introduction 1 Methods 2 Desorption Methods 2 Gas Analyses 4 Adsorption Analyses 14 Desorption Results and Gas Chemistry by Coal Bed and Coal Zone 14 Sewickley Coal Bed (Mined) 14 Redstone Coal Bed 14 Pittsburgh Roof Coal Interval 15 Pittsburgh Coal Bed (Mined) 16 Little Pittsburgh Coal Bed 17 Elk Lick Coal Bed 19 Brush Creek Coal Bed 19 Upper Kittanning Coal Bed 20 Middle Kittanning Coal Zone 20 Clarion Coal Zone 23 Upper Mercer Coal Bed 24 Lower Mercer Coal Bed 25 Quakertown Coal Zone 25 Isotope Analyses 26 Adsorption Results 26 Upper Kittanning Coal Bed 28 Middle Kittanning Coal Zone 29 Clarion Coal Zone 29 Conclusions 31 References Cited 31 Appendix A. Desorption Data for Coal Samples Retrieved From a Borehole at Mylan Park, Monongalia County, W. Va 33
7. Little Pittsburgh coal bed 19
8. Elk Lick coal bed 19
9. Brush Creek coal bed 20
10. Upper Kittanning coal bed 21
11. Middle Kittanning coal zone 22
12. Clarion coal zone 23
13. Upper Mercer coal bed 24
14. Lower Mercer coal bed 24
15. Quakertown coal zone 25
16. Bernard diagram for Mylan Park coal-bed-gas samples 26
17. Enlargement of the thermogenic sector of the Bernard diagram showing where composite coal-bed-gas samples from entire coal beds and coal zones, individual canisters, or composite samples from one or two canisters from a single coal bed or coal zone plot on the diagram 27 18.-21. Graphs showing—
18. Relation between carbon dioxide and methane variation with coal rank 28
19. Maximum carbon-dioxide and methane adsorption curves for coal samples from the Upper Kittanning coal bed in the Mylan Park borehole 29
20. Maximum carbon-dioxide and methane adsorption curves for coal samples from the Middle Kittanning coal zone in the Mylan Park borehole 30
21. Maximum carbon-dioxide and methane adsorption curves for coal samples from the Clarion coal zone in the Mylan Park borehole 30 Tables
1. Coal bed or zone name, depth of sample, and canister number for desorbed coal samples from the Mylan Park borehole, Monongalia County, W. Va 3
2. Selected proximate analyses for coals from the Mylan Park borehole, Monongalia County, W. Va 4
3. Comparison of gas constituents analyzed in coal samples from the Mylan Park borehole, Monongalia County, W. Va., by the Department of Energy National Energy Technology Laboratory and Isotech Laboratories, Inc 4
4. Isotopic composition of carbon and hydrogen (deuterium) in methane in gas samples from coal beds or zones from the Mylan Park borehole, Monongalia County, W. Va 5
5. Raw gas geochemistry analyses for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va 6
6. Gas geochemistry analyses corrected for air contamination for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va 10
Conversion Factors Multiply By To obtain Length inch (in.) centimeter (cm) inch (in.) millimeter (mm) foot (ft) meter (m) millimeter (mm) inch (in.) Volume cubic inch (in3) cubic centimeter (cm3) cubic inch (in3) milliliter (mL) cubic foor (ft3) cubic meter (m3) cubic centimeter (cm3 or cc) cubic inch (in3) milliliter (mL) cubic inch (in3) Mass gram (g) ounce, avoirdupois (oz) Pressure inch of mercury at 60°F (in Hg) kilopascal (kPa) pound per square inch (lb/in2 or PSIA) kilopascal (kPa) Calorific value British thermal unit (Btu) 1,055.056 joule (J) Temperature in degrees Fahrenheit (°F) may be converted to degrees Celsius (°C) as follows: °C=(°F-32)/1.8 Gas desorption volumes are provided in cubic centimeters, which is abbreviated using the standard industry abbreviation, cc, instead of cm3. Gas content measurements are provided in both standard cubic feet per ton (SCF/ton) and cubic centimeters per gram (cc/g). The abbreviations are those used by the oil and gas industry. Hydrostatic pressure for coal is measured in pounds per square inch of area (PSIA, an industry abbreviation). The Langmuir volume is the maximum gas capacity of the coal and is measured in standard cubic feet per ton (SCF/ton) or cubic centimers per gram (cc/g). The Langmuir pressure is the pressure at which the coal absorbs half of its maximum gas capacity; it is measured in pounds per square inch of area (PSIA). The isotopic composition of carbon (carbon 13, 13C) in methane is reported as the deviation (expressed as δ13C) in units of parts per thousand (per mil) relative to the Vienna Peedee belemnite (VPDB) standard. The isotopic composition of hydrogen (deuterium, 2H) in methane is reported as the deviation (expressed as δ2H) in per mil relative to the Vienna standard mean ocean water (VSMOW).
Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia By Leslie F. Ruppert,1 Nick Fedorko,2 Peter D. Warwick,1 William C. Grady,3 James Q. Britton,3 William A. Schuller,4 and Robert D. Crangle, Jr.1 Abstract The Department of Energy National Energy Technol ogy Laboratory funded drilling of a borehole (39.64378°N., 80.04376°W.) to evaluate the potential for coalbed-methane and carbon-dioxide sequestration at Mylan Park, a public park in Monongalia County, W. Va. The total depth of the borehole was 2,525 feet (ft) and contained 1,483.41 ft of Pennsylva nian coal-bearing strata, 739.67 ft of Mississippian strata, and 301.93 ft of Devonian strata. The drill site was located directly over abandoned mines in the Pittsburgh and Sewickley coal beds. Coal cores from remaining Pittsburgh and Sewickley coal-bed-mine pillars were cut and retrieved for desorption from both mines. In addition, coals were cored and desorbed from the Redstone, Pittsburgh roof coal interval, Little Pittsburgh, Elk Lick, Brush Creek, Upper Kittanning, Middle Kittanning, Clarion, Upper Mercer, Lower Mercer, and Quakertown coal beds and coal zones. All coals are Pennsylvanian in age and are high-volatile A bituminous in rank. A total of 34.75 ft of coal was desorbed over a maximum period of 662 days, although most of the coal was desorbed for about 275 days. Measured raw-total-gas contents ranged from 0.43 standard cubic feet per ton (SCF/ton, an industry abbreviation) for the mined Sewickley coal bed to 130.98 SCF/ton for the Upper Kittanning coal bed. Volumes of residual gas were not measured; therefore, the gas volumes reported here should be regarded as minimum volumes. The amount of oxygen in the gas samples collected from the desorption canisters ranged from 2.55 to 20.13 percent. Methane contents ranged from 0 percent for one single canis ter from the Pittsburgh (WV-02-B3-4) and Little Pittsburgh (WV-02-CB3-2) coal beds to almost 81 percent for two canisters from the Clarion coal zone (WV-02-B3-16 and WV-02-B3-17), which suggests that all of the gas samples were contaminated to some degree by air. Therefore, all gas compositions reported have been normalized to remove the air. With a single exception (the Quakertown coal zone), the coals from the Mylan Park study area are thermogenic in origin with the isotopic composition of carbon (carbon 13, 13C) in meth ane (expressed as δ13C in units of parts per thousand (per mil) relative to the Vienna Peedee belemnite (VPDB) standard) ranging from -32.39 to -50.66 per mil and ratios of methane to hydrocarbons of higher molecular weight ranging from 10 to 53. The Quakertown coal zone has a C1/C2+ ratio of 913, sug gesting that it contains some microbial gas. High-pressure carbon-dioxide adsorption isotherms were measured on composite coal samples of the Upper Kittanning coal bed and the Middle Kittanning and Clarion coal zones. Assuming that the reservoir pressure in the Mylan Park coals is equivalent to the normal hydrostatic pressure, the estimated maximum carbon-dioxide adsorption pressures range from a low of about 300 pounds per square inch (lb/in2) in coals from the Clarion coal zone to 500 lb/in2 for coals from the Upper Kittanning coal bed. The estimated maximum methane adsorp tion isotherms show that the coals from the Upper Kittanning coal bed and the Middle Kittanning coal zone are undersatu rated in methane, but coals from the Clarion coal zone are close to saturation. Introduction Personnel at Mylan Park, Monongalia County, W. Va. (fig. 1), requested funding from the U.S. Department of Ener gy's National Energy Technology Laboratory (DOE-NETL) to evaluate the potential of using coalbed methane to power the park's electric lights and equipment. NETL responded and provided funding to drill a borehole within the park boundar ies to evaluate the potential for coalbed-methane and carbondioxide sequestration. Drilling started on September 23, 2002, and was completed on November 14, 2002, running 5-day, 12-hour shifts per week with some down time. The West Vir ginia Geological and Economic Survey (WVGES) and EG&G Technical Services, Inc., Morgantown, W. Va., coordinated the borehole drilling, electric logging, and the methane desorption 1U.S. Geological Survey, Reston, Va. 2Consultant, Moatsville, W. Va. 3West Virginia Geological and Economic Survey, Morgantown, W. Va. 4EG&G Technical Services, Inc., Morgantown, W. Va.
2 Coal and Petroleum Resources in the Appalachian Basin work. The geologist's log was published in appendix 1 of Ruppert and others (2004) and additional drilling descrip tions can be obtained through the West Virginia Geological and Economic Survey (2007). The borehole was drilled by L.J. Hughes & Sons, Summersville, W. Va., and Marshall J. Miller and Associates of Bluefield, Va., electric logged the hole. U.S. Geological Survey (USGS) personnel conducted all methane desorption work. After desorption was completed, the coal was analyzed in the WVGES laboratory. In addition, the return fluids and cuttings were logged throughout drilling by Hydrocarbon Well Logging Services of Parkersburg, W. Va. The 2,525 feet (ft) of core contained 1,483.41 ft of Pennsylva nian coal-bearing strata, 739.67 ft of Mississippian strata, and 301.93 ft of Devonian strata (fig. 2). Methods Desorption Methods Procedures modified from Stricker and others (2000), Gas Research Institute (1995), and Barker and others (2002) were followed throughout the coring and desorption to mea sure gas contents of the coals. During coring, both the time that the coal was retrieved off the bottom (base of the bore hole) and the temperature of water circulating in the borehole were recorded in order to estimate the amount of lost gas (the volume of gas desorbed between the time the core was retrieved from the bottom and the time that the coal was sealed in a desorption canister) and reservoir temperature, respec tively. As soon as the core barrel was recovered at the surface, Figur e 1 - Refe r to Cap tion Figure 1. Generalized location map of the Mylan Park study area in Monongalia County, W. Va. Figure 2 - R efer to Caption
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 3 the core was extracted onto a wooden core holder, quickly described (coal versus rock), and measured. The coal was removed from the wooden core holder in a graduated curved polyvinyl-chloride (PVC) scoop to keep it intact, weighed, and placed in thin (approximately 4-mm thick) sheet plastic sleeves with holes to maintain the stratigraphic integrity of the coal during desorption. Within 10 to 23 minutes of reach ing the surface, coal intervals from the Sewickley, Redstone, and Pittsburgh coal beds were placed in 2-ft-long aluminum canisters and 1-ft-long PVC canisters and cores from other coal beds were placed in 1-ft-long PVC canisters (table 1). All of the canisters were filled with distilled water in order to eliminate headspace (the volume of air left in the canister), sealed, and placed in water baths kept at reservoir temperature (68°F-70°F, as estimated from the temperature of circulating borehole water). This temperature was roughly equivalent to measured reservoir temperatures in other boreholes within Monongalia County, W. Va. Desorbed gas volumes were initially measured after 10 minutes from the time that the canisters were sealed. To obtain volumes, the canister valves were opened and the volumet ric displacement of water in a graduated manometer was recorded. In addition, the ambient air and water-bath tem perature and the atmospheric pressure were recorded during each desorption measurement to correct desorbed gas volumes according to standard temperature and pressure (STP). Each canister was measured approximately every 10 minutes for the first half hour to hour, and then every 20 to 30 minutes for the first day. Canisters were not monitored overnight, but measured upon reaching the drill site in the morning. After approximately 3 weeks, the canisters were moved to a labora tory at the USGS where they were measured once a day for 2 weeks. Over the course of the desorption, the canisters were measured less frequently because less gas was desorbed from the coals. Toward the end of the desorption tests, the canisters were measured bimonthly. See appendix A for desorption data for all of the coal samples. Lost gas was estimated using the graphical methods found in Barker and others (2002). Diffusion rates of coals from the Mylan Park study area were low; thus, lost gas volumes were very low, ranging from 0 cubic centimeters (cc, an abbreviation commonly used in oil and gas geochemical reports) for most of the coal intervals to about 60 cc in the coal from the Elk Lick coal bed (canister 1, WV-01-B3-6). See appendix A for lost gas amounts. Figure 2 (facing page). Generalized stratigraphic column showing Pennsylvanian coal beds and coal zones from which samples were desorbed for coalbed-methane content in the Mylan Park study area, Monongalia County, W. Va. (Based on Rice and others, 1994.) Table 1. Coal bed or zone name, depth of sample, and canister number for desorbed coal samples from the Mylan Park borehole, Monongalia County, W. Va. Coal bed or coal zone Depth of sample (feet) Canister number Sewickley coal bed 346.80-347.20 Canister 1: WV-02-CB3-10 347.20-348.20 Canister 2: WV-02-B3-1 348.20-350.20 Canister 3: WV-02-US4-2 350.20-352.20 Canister 4: WV-02-US4-1 Redstone coal bed 405.30-407.30 Canister 1: WV-02-US4-5 407.30-408.00 Canister 2: WV-02-B3-2 Pittsburgh roof coal interval 426.96-427.96 Canister 1: WV-02-B3-3 432.35-433.25 Canister 2: WV-02-B3-5 Pittsburgh coal bed 433.85-434.35 Canister 1: WV-02-B3-4 434.35-436.35 Canister 2: WV-02-US4-30 436.35-438.35 Canister 3: WV-02-US4-14 438.35-440.35 Canister 4: WV-02-US4-8 440.35-442.35 Canister 5: WV-02-US4-6 Little Pittsburgh coal bed 468.50-469.25 Canister 1: WV-02-CB3-2 Elk Lick coal bed 659.93-660.60 Canister 1: WV-02-B3-6 Brush Creek coal bed 920.40-921.10 Canister 1: WV-02-B3-7 921.10-921.80 Canister 2: WV-02-B3-8 Upper Kittanning coal bed 1,121.70-1,122.70 Canister 1: WV-02-B3-9 1,122.70-1,123.40 Canister 2: WV-02-B3-10 Middle Kittanning coal zone 1,184.10-1,185.10 Canister 1: WV-02-B3-11 1,185.10-1,185.40 Canister 2: WV-02-CB3-12 1,188.00-1,189.00 Canister 3: WV-02-B3-12 1,189.00-1,190.00 Canister 4: WV-02-B3-13 1,190.00-1,190.45 Canister 5: WV-02-CB3-11 Clarion coal zone 1,270.50-1,271.50 Canister 1: WV-02-B3-14 1,271.50-1,272.35 Canister 2: WV-02-B3-15 1,278.70-1,279.70 Canister 3: WV-02-B3-16 1,279.70-1,280.80 Canister 4: WV-02-B3-17 Upper Mercer coal bed 1,324.40-1,325.15 Canister 1: WV-02-B3-18 Lower Mercer coal bed 1,357.50-1,358.50 Canister 1: WV-02-B3-19 Quakertown coal zone 1,465.00-1,465.60 Canister 1: WV-02-B3-20 1,475.60-1,476.43 Canister 2: WV-02-B3-21
4 Coal and Petroleum Resources in the Appalachian Basin Residual gas was not measured because coal cores were the property of the WVGES and all of the coal was used for proximate (table 2), petrographic, geochemical, and adsorp tion analyses. Although desorption tests were conducted over a long period of time, the volumes of residual gas in the coal may be substantial; therefore, the reported raw and dry, ash-free (daf) total gas volumes cited in this report should be regarded as minimum volumes. For example, Diamond and others (1986) report that residual gas can average up to 20 per cent of the total gas content. A.K. Markowski (Pennsylvania Bureau of Topographic and Geologic Survey, oral commun., 2004) reports that residual gas she measured in cores from Pennsylvania and West Virginia can be as high as 35 percent. In a companion study (see Ruppert and others, this volume, chap. G.4), residual gas contents were as high as 40 percent of the total gas content. Gas Analyses Gas was sampled intermittently throughout the desorp tion process, starting within 1 to 2 days after the canisters were sealed. Gas volumes were measured in the manometer and samples were collected directly from the manometer with a short (approximately 5-in-long) piece of plastic tub ing and bled into Tedlar bags. The bags were shipped to the Table 2. Selected proximate analyses for coals from the Mylan Park borehole, Monongalia County, W. Va. Coal bed or zone Depth of sample (feet) Moisture (percent) Volatile matter, dry (percent) Volatile matter, asreceived (percent) Volatile matter, mineralmatter free (percent) Ash, dry (percent) Ash, asreceived (percent) Fixed carbon, dry (percent) Fixed car bon, as received (percent) Fixed carbon, moist, mineralmatter free (percent) Calorific value (British thermal units) Sewickley coal bed 346.80-352.20 11,498 Redstone coal bed 405.30-408.00 10,572 Pittsburgh roof coal interval 426.96-433.25 12,231 Pittsburgh coal bed 433.85-442.35 13,557 Little Pittsburgh coal bed 468.50-469.25 7,880 Elk Lick coal bed 659.93-660.60 10,990 Brush Creek coal bed 920.40-921.80 8,471 Upper Kittanning coal bed 1,121.70-1,123.40 13,785 Middle Kittanning coal zone 1,184.10-1,190.45 12,232 Clarion coal zone 1,270.50-1,280.80 10,735 Upper Mercer coal bed 1,324.40-1,325.15 13,611 Lower Mercer coal bed 1,357.50-1,358.50 10,629 Quakertown coal zone 1,465.00-1,476.43 9,290 Table 3. Comparison of gas constituents analyzed in coal samples from the Mylan Park borehole, Monongalia County, W. Va., by the Department of Energy National Energy Technology Laboratory and Isotech Laboratories, Inc. Constituents of gas Department of Energy, National Energy Technical Laboratory Isotech Laboratories, Inc. Carbon monoxide (CO) Nitrogen (N2) Oxygen (O2) Carbon dioxide (CO2) Hydrogen (H2) Helium (He) Argon (Ar) Methane (CH4 (or C1)) Ethane (C2H6 (or C2)) Ethylene (C2H4) Propane (C3H8 (or C3)) iso-butane (iC4H10 (or iC4)) n-butane (nC4H10 (or nC4)) iso-pentane (iC5H12 (or iC5)) n-pentane (nC5H12 (or nC5)) Hexane (C6+)
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 5 DOE-NETL labs for the initial analyses; additional analyses were performed by a commercial laboratory (Isotech Labo ratories, Inc.). Table 3 shows gas constituents analyzed by both laboratories, as follows: CO, N2, O2, Ar, CO2, H2, He, methane (CH4, also denoted as C1), ethane (C2H6, also denoted as C2), ethylene (C2H4), propane (C3H8, also denoted as C3), iso-butane (iC4H10, also denoted as iC4), n-butane (nC4H10, also denoted as nC4), iso-pentane (iC5H12, also denoted as iC5), n-pentane (nC5H12, also denoted as nC5), and hexanes (denoted as C6+). Results for hydrocarbon species were reported in parts per million (ppm) and converted to weight percent for this report. In addition, if samples contained sufficient gas, the isotopic composition of carbon (carbon 13, 13C) in methane (reported as the deviation (expressed as δ13C) in units of parts per thousand (per mil) relative to the Vienna Peedee belemnite (VPDB) standard) and the isotopic composition of hydro gen (deuterium, 2H) in methane (reported as the deviation (expressed as δ2H) in per mil relative to the Vienna standard mean ocean water (VSMOW)) were analyzed to determine gas origin (biogenic versus thermogenic) following the method in Bernard and others (1978). Enough gas was present in coals from the Pittsburgh, Brush Creek, Upper Kittanning, Middle Kittanning, Clarion, Upper Mercer, Lower Mercer, and Quak ertown coal beds and coal zones to perform isotopic analyses (see table 4). The use of a short tube to collect gases from the mano meter and evacuate it into gas collection bags did not pre clude air contamination in the samples. To remove the air, we normalized all of the gas analyses (table 5) to an air-free basis (table 6) by zeroing out oxygen. An examination of the air-free analyses shows a significant nitrogen depletion in many of the samples (table 6) that were run by Isotech Laboratories, Inc. The laboratory reports show no systematic errors in the analy ses of coals from the Mylan Park study area (Steve Pelphrey, Isotech Laboratories, Inc., oral commun., 2004). We do not have an explanation for the nitrogen depletion; however, it does not affect either the accuracy of the hydrocarbon analyses or the ratio of methane to hydrocarbons of higher molecular weight. Table 4. Isotopic composition of carbon and hydrogen (deuterium) in methane in gas samples from coal beds or zones from the Mylan Park borehole, Monongalia County, W. Va. [By convention, isotope compositions are reported as the deviation (δ) of values in units of parts per thousand (per mil) relative to a known reference standard. The reference standard for isotopes of carbon (carbon-13, 13C) is the Vienna Peedee belemnite (VPDB) and the reference standard for hydrogen (deuterium, 2H) is the Vienna standard mean ocean water (SMOW). See Kendall and Caldwell (1998) for fundamental information on isotope analyses. Other abbreviations are as follows: nd, no data] Sample number Canister Coal bed or zone δ13C1 (per mil) δ2H (per mil) WV-02-US-4, WV-02-US-6, WV-02-US-8, WV-02-US-14, WV-02-US-30 Pittsburgh coal bed WV-02-B3-7, WV-02-B3-8 Brush Creek coal bed WV-02-B3-7, WV-02-B3-8 Brush Creek coal bed WV-02-B3-9, WV-02-B3-10 Upper Kittanning coal bed WV-02-B3-11, WV-02-CB3-12 Middle Kittanning coal zone WV-02-B3-11, WV-02-CB3-12 Middle Kittanning coal zone WV-02-CB3-11, WV-02-B3-12, WV-02-B3-13 Middle Kittanning coal zone WV-02-CB3-11 Middle Kittanning coal zone WV-02-B3-12, WV-02-B3-13 Middle Kittanning coal zone WV-02-B3-14, WV-02-B3-15 Clarion coal zone, upper split WV-02-B3-14, WV-02-B3-15 Clarion coal zone, upper split WV-02-B3-14 Clarion coal zone, upper split WV-02-B3-15 Clarion coal zone, upper split WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split WV-02-B3-18 Upper Mercer coal bed WV-02-B3-19 Lower Mercer coal bed WV-02-B3-20, WV-02-B3-21 Quakertown coal zone nd
6 Coal and Petroleum Resources in the Appalachian Basin Table 5. Raw gas geochemistry analyses for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va.—Continued [These analyses are raw and uncorrected for air contamination. Abbreviations are as follows: cc, cubic centimeters; He, helium; H2, hydrogen; Ar, argon; O2, oxygen; CO2, carbon dioxide; N2, nitrogen; CO, carbon monoxide; C1, methane; C2, ethane + ethylene; C2H4, ethylene; C3, propane; iC4, iso-butane; nC4, n-butane; iC5, iso-pentane; nC5, n-pentane; C6+, hexanes. Argon, a constituent in air, is required for recalculating gas chemistry to an air-free basis. Because argon is not reported by the Department of Energy National Energy Technology Laboratory, the mean argon content (0.4999 weight percent) in the gas samples analyzed by Isotech Laboratories, Inc., was used for the calculation] Sample number Canister numbers Coal bed or zone Depth (feet) Gas, cumulative volume (cc) Sampling date He (percent) H2 (percent) DOE-MP No. 3 WV-02-B3-3 Pittsburgh roof coal interval 426.96-427.96 10/4/2002 nd DOE-MP No. 5 WV-02-B3-4 Pittsburgh coal bed 433.85-434.35 10/7/2002 nd DOE-MP No. 2 WV-02-US-4, WV-02-US-6, WV-02-US-8, WV-02-US-14, WV-02-US-30, WV-02-B3-4 Pittsburgh coal bed 433.85-442.35 10/2/2002 nd WV-02-US-4, WV-02-US-6, WV-02-US-8, WV-02-US-14, WV-02-US-30 Pittsburgh coal bed 433.85-440.35 10/11/2002 DOE-MP No. 1 WV-02-CB3-2 Little Pittsburgh coal bed 468.50-469.25 10/2/2002 nd DOE-MP No. 11 WV-02-CB3-2 Little Pittsburgh coal bed 468.50-469.25 10/10/2002 nd DOE-MP No. 4 WV-02-B3-6 Elk Lick coal bed 659.93-660.60 10/4/2002 nd DOE-MP No. 6 WV-02-B3-6 Elk Lick coal bed 659.93-660.60 10/7/2002 nd DOE-MP No. 12 WV-02-B3-6 Elk Lick coal bed 659.93-660.60 10/10/2002 nd WV-02-B3-6 Elk Lick coal bed 659.93-660.60 1,222 11/25/2003 DOE-MP No. 7 WV-02-B3-7, WV-02-B3-8 Brush Creek coal bed 920.40-921.80 10/8/2002 nd WV-02-B3-7, WV-02-B3-8 Brush Creek coal bed 920.40-921.80 10/11/2002 WV-02-B3-7, WV-02-B3-8 Brush Creek coal bed 920.40-921.80 3,199 11/25/2003 DOE-MP No. 14 WV-02-B3-9 Upper Kittanning coal bed 1,121.70-1,122.70 10/10/2002 nd DOE-MP No. 13 WV-02-B3-10 Upper Kittanning coal bed 1,122.70-1,123.40 10/10/2002 nd DOE-MP No. 10 WV-02-B3-9, WV-02-B3-10 Upper Kittanning coal bed 1,121.70-1,123.40 10/10/2002 nd WV-02-B3-9, WV-02-B3-10 Upper Kittanning coal bed 1,121.70-1,123.40 5,522 11/25/2003 DOE-MP No. 9 WV-02-B3-11, WV-02-CB3-12 Middle Kittanning coal zone 1,184.10-1,185.40 10/10/2002 nd DOE-MP No. 8 WV-02-B3-11 Middle Kittanning coal zone 1,184.10-1,185.10 10/10/2002 nd WV-02-B3-11, WV-02-CB3-12 Middle Kittanning coal zone 1,184.10-1,185.40 10/11/2002 WV-02-B3-11, WV-02-CB3-12 Middle Kittanning coal zone 1,184.10-1,185.40 3,562 11/25/2003 WV-02-B3-12, WV-02-B3-13, WV-02-CB3-11 Middle Kittanning coal zone 1,188.00-1,190.45 1,141 10/11/2002 WV-02-B3-12, WV-02-B3-13, WV-02-CB3-11 Middle Kittanning coal zone 1,188.00-1,190.45 4,173 11/27/2002 DOE-MP No. 18 WV-02-CB3-11 Middle Kittanning coal zone 1,190.00-1,190.45 10/10/2002 nd WV-02-CB3-11 Middle Kittanning coal zone 1,190.00-1,190.45 1,753 11/25/2003
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 7 Table 5. Raw gas geochemistry analyses for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va.—Continued Ar (percent) O2 (percent) CO2 (percent) N2 (percent) CO (percent) (percent) (percent) C2H4 (percent) (percent) (percent) nC4 (percent) (percent) nC5 (percent) C6+ (percent) nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd
8 Coal and Petroleum Resources in the Appalachian Basin Table 5. Raw gas geochemistry analyses for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va.—Continued [These analyses are raw and uncorrected for air contamination. Abbreviations are as follows: cc, cubic centimeters; He, helium; H2, hydrogen; Ar, argon; O2, oxygen; CO2, carbon dioxide; N2, nitrogen; CO, carbon monoxide; C1, methane; C2, ethane + ethylene; C2H4, ethylene; C3, propane; iC4, iso-butane; nC4, n-butane; iC5, iso-pentane; nC5, n-pentane; C6+, hexanes. Argon, a constituent in air, is required for recalculating gas chemistry to an air-free basis. Because argon is not reported by the Department of Energy National Energy Technology Laboratory, the mean argon content (0.4999 weight percent) in the gas samples analyzed by Isotech Laboratories, Inc., was used for the calculation] Sample number Canister numbers Coal bed or zone Depth (feet) Gas, cumulative volume (cc) Sampling date He (percent) H2 (percent) DOE-MP No. 15 WV-02-B3-11, WV-02-B3-12 Middle Kittanning coal zone 1,184.10-1,185.10 10/10/2002 nd 1,188.00-1,189.00 DOE-MP No. 17 WV-02-B3-12 Middle Kittanning coal zone 1,188.00-1,189.00 10/10/2002 nd DOE-MP No. 16 WV-02-B3-13 Middle Kittanning coal zone 1,189.00-1,190.00 10/10/2002 nd WV-02-B3-12, WV-02-B3-13 Middle Kittanning coal zone 1,188.00-1,190.00 6,294 11/25/2003 WV-02-B3-14, WV-02-B3-15 Clarion coal zone, upper split 1,270.50-1,272.35 10/11/2002 WV-02-B3-14, WV-02-B3-15 Clarion coal zone, upper split 1,270.50-1,272.35 1,691 11/27/2002 WV-02-B3-14 Clarion coal zone, upper split 1,270.50-1,271.50 1,102 11/25/2003 WV-02-B3-15 Clarion coal zone, upper split 1,271.50-1,272.35 2,696 11/25/2003 DOE-MP No. 19 WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split 1,278.70-1,280.80 10/11/2002 nd WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split 1,278.70-1,280.80 10/11/2002 WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split 1,278.70-1,280.80 4,198 11/27/2002 WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split 1,278.70-1,280.80 7,309 11/25/2003 DOE-MP No. 21 WV-02-B3-18 Upper Mercer coal bed 1,324.40-1,325.15 10/11/2002 nd WV-02-B3-18 Upper Mercer coal bed 1,324.40-1,325.15 1,072 11/27/2002 WV-02-B3-18 Upper Mercer coal bed 1,324.40-1,325.15 1,790 11/25/2003 DOE-MP No. 20 WV-02-B3-19 Lower Mercer coal bed 1,357.50-1,358.50 10/11/2002 nd WV-02-B3-19 Lower Mercer coal bed 1,357.50-1,358.50 11/27/2002 WV-02-B3-19 Lower Mercer coal bed 1,357.50-1,358.50 1,098 11/25/2003 DOE-MP No. 23 WV-02-B3-20 Quakertown coal zone 1,465.00-1,465.60 10/15/2002 nd DOE-MP No. 22 WV-02-B3-21 Quakertown coal zone 1,475.60-1,476.43 10/15/2002 nd WV-02-B3-20, WV-02-B3-21 Quakertown coal zone 1,465.60-1,476.43 1,829 11/27/2002
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 9 Table 5. Raw gas geochemistry analyses for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va.—Continued Ar (percent) O2 (percent) CO2 (percent) N2 (percent) CO (percent) (percent) (percent) C2H4 (percent) (percent) (percent) nC4 (percent) (percent) nC5 (percent) C6+ (percent) nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd
10 Coal and Petroleum Resources in the Appalachian Basin Table 6. Gas geochemistry analyses corrected for air contamination for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va.—Continued [These analyses are corrected for air contamination and presented to two decimal points. Abbreviations are as follows: cc, cubic centimeters; H2, hydrogen; Ar, argon; CO, carbon monoxide; O2, oxygen; N2, nitrogen; CO, carbon monoxide; C1, methane; C2, ethane + ethylene; C2H4, ethylene; C3, propane; iC4, iso-butane; nC4, n-butane; iC5, iso-pentane; nC5, n-pentane; C6+, hexanes; C2+, methane + ethane + ethylene + propane + iso-butane + n-butane + iso-pentane + n-pentane + hexanes. Argon, a constituent in air, is required for recalculating gas chemistry to an air-free basis. Because argon is not reported by the Depart ment of Energy National Energy Technology Laboratory, the mean argon content (0.4999 weight percent) in the gas samples analyzed by Isotech Laboratories, Inc., was used for the calculations] Sample number Canister numbers Coal bed or zone Depth (feet) Gas, cumulative volume (cc) Sampling date H2 (percent) Ar (percent) DOE-MP No. 3 WV-02-B3-3 Pittsburgh roof coal interval 426.96-427.96 10/4/2002 nd DOE-MP No. 5 WV-02-B3-4 Pittsburgh coal bed 433.85-434.35 10/7/2002 nd DOE-MP No. 2 WV-02-US-4, WV-02-US-6, WV-02-US-8, WV-02-US-14, WV-02-US-30, WV-02-B3-4 Pittsburgh coal bed 433.85-442.35 10/2/2002 nd WV-02-US-4, WV-02-US-6, WV-02-US-8, WV-02-US-14, WV-02-US-30 Pittsburgh coal bed 433.85-440.35 10/11/2002 DOE-MP No. 1 WV-02-CB3-2 Little Pittsburgh coal bed 468.50-469.25 10/2/2002 nd DOE-MP No. 11 WV-02-CB3-2 Little Pittsburgh coal bed 468.50-469.25 10/10/2002 nd DOE-MP No. 4 WV-02-B3-6 Elk Lick coal bed 659.93-660.60 10/4/2002 nd DOE-MP No. 6 WV-02-B3-6 Elk Lick coal bed 659.93-660.60 10/7/2002 DOE-MP No. 12 WV-02-B3-6 Elk Lick coal bed 659.93-660.60 10/10/2002 WV-02-B3-6 Elk Lick coal bed 659.93-660.60 1,222 11/25/2003 DOE-MP No. 7 WV-02-B3-7, WV-02-B3-8 Brush Creek coal bed 920.40-921.80 10/8/2002 nd WV-02-B3-7, WV-02-B3-8 Brush Creek coal bed 920.40-921.80 10/11/2002 WV-02-B3-7, WV-02-B3-8 Brush Creek coal bed 920.40-921.80 3,199 11/25/2003 DOE-MP No. 14 WV-02-B3-9 Upper Kittanning coal bed 1,121.70-1,122.70 10/10/2002 nd DOE-MP No. 13 WV-02-B3-10 Upper Kittanning coal bed 1,122.70-1,123.40 10/10/2002 DOE-MP No. 10 WV-02-B3-9, WV-02-B3-10 Upper Kittanning coal bed 1,121.70-1,123.40 10/10/2002 nd WV-02-B3-9, WV-02-B3-10 Upper Kittanning coal bed 1,121.70-1,123.40 5,522 11/25/2003 DOE-MP No. 9 WV-02-B3-11, WV-02-CB3-12 Middle Kittanning coal zone 1,184.10-1,185.40 10/10/2002 nd DOE-MP No. 8 WV-02-B3-11 Middle Kittanning coal zone 1,184.10-1,185.10 10/10/2002 WV-02-B3-11, WV-02-CB3-12 Middle Kittanning coal zone 1,184.10-1,185.40 10/11/2002 WV-02-B3-11, WV-02-CB3-12 Middle Kittanning coal zone 1,184.10-1,185.40 3,562 11/25/2003 WV-02-B3-12, WV-02-B3-13, WV-02-CB3-11 Middle Kittanning coal zone 1,188.00-1,190.45 1,141 10/11/2002 WV-02-B3-12, WV-02-B3-13, WV-02-CB3-11 Middle Kittanning coal zone 1,188.00-1,190.45 4,173 11/27/2002 DOE-MP No. 18 WV-02-CB3-11 Middle Kittanning coal zone 1,190.00-1,190.45 10/10/2002
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 11 Table 6. Gas geochemistry analyses corrected for air contamination for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va.—Continued CO2 (percent) O2 (percent) N2 (percent) CO (percent) (percent) (percent) C2H4 (percent) (percent) (percent) nC4 (percent) (percent) nC5 (percent) C6+ (percent) C2+ (percent) C1/C2+ (ratio) nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd
12 Coal and Petroleum Resources in the Appalachian Basin Table 6. Gas geochemistry analyses corrected for air contamination for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va.—Continued [These analyses are corrected for air contamination and presented to two decimal points. Abbreviations are as follows: cc, cubic centimeters; H2, hydrogen; Ar, argon; CO, carbon monoxide; O2, oxygen; N2, nitrogen; CO, carbon monoxide; C1, methane; C2, ethane + ethylene; C2H4, ethylene; C3, propane; iC4, iso-butane; nC4, n-butane; iC5, iso-pentane; nC5, n-pentane; C6+, hexanes; C2+, methane + ethane + ethylene + propane + iso-butane + n-butane + iso-pentane + n-pentane + hexanes. Argon, a constituent in air, is required for recalculating gas chemistry to an air-free basis. Because argon is not reported by the Depart ment of Energy National Energy Technology Laboratory, the mean argon content (0.4999 weight percent) in the gas samples analyzed by Isotech Laboratories, Inc., was used for the calculations] Sample number Canister numbers Coal bed or zone Depth (feet) Gas, cumulative volume (cc) Sampling date H2 (percent) Ar (percent) WV-02-CB3-11 Middle Kittanning coal zone 1,190.00-1,190.45 1,753 11/25/2003 DOE-MP No. 15
WV-02-B3-11, WV-02-B3-12 Middle Kittanning coal zone 1,184.10-1,185.10 1,188.00-1,189.00 10/10/2002
nd
DOE-MP No. 17 WV-02-B3-12 Middle Kittanning coal zone 1,188.00-1,189.00 10/10/2002 DOE-MP No. 16 WV-02-B3-13 Middle Kittanning coal zone 1,189.00-1,190.00 10/10/2002 WV-02-B3-12, WV-02-B3-13 Middle Kittanning coal zone 1,188.00-1,190.00 6,294 11/25/2003 WV-02-B3-14, WV-02-B3-15 Clarion coal zone, upper split 1,270.50-1,272.35 10/11/2002 WV-02-B3-14, WV-02-B3-15 Clarion coal zone, upper split 1,270.50-1,272.35 1,691 11/27/2002 WV-02-B3-14 Clarion coal zone, upper split 1,270.50-1,271.50 1,102 11/25/2003 WV-02-B3-15 Clarion coal zone, upper split 1,271.50-1,272.35 2,696 11/25/2003 DOE-MP No. 19 WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split 1,278.70-1,280.80 10/11/2002 nd WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split 1,278.70-1,280.80 10/11/2002 WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split 1,278.70-1,280.80 4,198 11/27/2002 WV-02-B3-16, WV-02-B3-17 Clarion coal zone, lower split 1,278.70-1,280.80 7,309 11/25/2003 DOE-MP No. 21 WV-02-B3-18 Upper Mercer coal bed 1,324.40-1,325.15 10/11/2002 nd WV-02-B3-18 Upper Mercer coal bed 1,324.40-1,325.15 1,072 11/27/2002 WV-02-B3-18 Upper Mercer coal bed 1,324.40-1,325.15 1,790 11/25/2003 DOE-MP No. 20 WV-02-B3-19 Lower Mercer coal bed 1,357.50-1,358.50 10/11/2002 nd WV-02-B3-19 Lower Mercer coal bed 1,357.50-1,358.50 11/27/2002 WV-02-B3-19 Lower Mercer coal bed 1,357.50-1,358.50 1,098 11/25/2003 DOE-MP No. 23 WV-02-B3-20 Quakertown coal zone 1,465.00-1,465.60 10/15/2002 nd DOE-MP No. 22 WV-02-B3-21 Quakertown coal zone 1,475.60-1,476.43 10/15/2002 nd WV-02-B3-20, WV-02-B3-21 Quakertown coal zone 1,465.60-1,476.43 1,829 11/27/2002
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 13 Table 6. Gas geochemistry analyses corrected for air contamination for coal samples from core retrieved from the Mylan Park borehole, Monongalia County, W. Va.—Continued CO2 (percent) O2 (percent) N2 (percent) CO (percent) (percent) (percent) C2H4 (percent) (percent) (percent) nC4 (percent) (percent) nC5 (percent) C6+ (percent) C2+ (percent) C1/C2+ (ratio) nd nd
nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd nd
14 Coal and Petroleum Resources in the Appalachian Basin Adsorption Analyses After desorption measurements were completed in December 2003, the canisters were unsealed and taken to the WVGES laboratory at West Virginia University in Morgan town, W. Va. The coals were split into representative subsam ples for petrographic, geochemical, and proximate analyses. In addition, samples from all canisters of the Upper Kittanning coal bed and the Clarion coal zone and from all but one of the canisters for the Middle Kittanning coal zone were selected for high-pressure carbon-dioxide adsorption analyses because the coal beds were relatively thick (1.70-3.95 ft), deep (1,112.70- 1,280.80 ft), and contained abundant gas (85.69-130.98 standard cubic feet per ton (SCF/ton), or 2.68-4.09 cubic cen timeters per gram (cc/g), on an as-received basis (arb)). (See sections below.) These analyses were performed to determine the maximum carbon-dioxide sorption capacity in coals from the Mylan Park study area. Samples for high-pressure carbon-dioxide adsorption analyzes were sent to RMB Earth Science Consultants, Ltd. (Delta, British Columbia, Canada), where they were crushed to -60 mesh and placed in an equilibrium moisture bath for 21 days. Isotherm analyses were conducted in a high-pressure volumetric adsorption apparatus at the reservoir temperature of 70°F. A known volume of gas was used to dose 100-gram (g) coal samples from the Upper Kittanning coal bed and the Middle Kittanning and Clarion coal zones, and the amount of gas adsorbed on equilibrated samples was determined using a series of pressure measurements. See Yee and others (1993) for detailed information on gas adsorption theory and analyses. Desorption Results and Gas Chemistry by Coal Bed and Coal Zone Sewickley Coal Bed (Mined) A 5.40-ft-long sample of coal from a remaining pillar in an abandoned underground mine of the Sewickley coal bed was cored and retrieved to the surface from a depth of 346.80 to 352.20 ft at 11:395 hours on September 27, 2002. A total of 7 or 8 measurements was taken on each canister over 3 days (fig. 3) until desorption was suspended because the coal-bedgas volumes could not be detected or measured. The measured raw-total-gas content for the Sewickley coal bed (using a weighted average) was 0.07 SCF/ton (0.00 cc/g). The overall moisture content was 1.29 percent and the ash yield was 21.08 weight percent (dry basis (db)) (table 2). Because the gas content was so low (fig. 3), the ash yields of the coal within individual canisters were not determined and the total gas con tent on a dry, ash-free basis (dafb) could not be determined. See tables A1, A2, A3, and A4 in appendix A for raw data. Canister 1 (WV-02-CB3-10; 346.80-347.20 ft)—No gas was desorbed over the 3 days. Canister 2 (WV-02-B3-1; 347.20-348.20 ft)—A measured gas volume was recorded only on the first measurement. The measured raw-total-gas content of the coal was 0.40 SCF/ton (0.01 cc/g) (based on the single measurement). Canister 3 (WV-02-US4-2; 348.20-350.20 ft)—The measured gas volumes were recorded on the first and second measurements. The measured raw-totalgas content of the coal was 0.01 SCF/ton (0.00 cc/g) (based on the two measurements). Canister 4 (WV-02-US4-1; 350.20-352.20 ft)—A measured gas volume was recorded only on the first measurement. The measured raw-total-gas content of the coal was 0.02 SCF/ton (0.00 cc/g) (based on the single measurement). Gas chemistry of the Sewickley coal bed.—There was insufficient gas from the Sewickley coal bed canisters to ana lyze for chemical constituents. Redstone Coal Bed A 2.70-ft-long sample of the Redstone coal bed was cored and retrieved to the surface from a depth of 405.30 to 408.00 ft at 15:01 hours on September 30, 2002, and placed into one 2-ft-long aluminum canister and one 1-ft-long PVC canister for desorption. The measured raw-total-gas content of the Redstone coal bed (using a weighted average) was low—0.5 SCF/ton (0.02 cc/g)—which can be attributed to gas migra tion due to the mining of the overlying Sewickley coal bed, the mining of the Pittsburgh coal bed, and a relatively shallow depth. The overall moisture content was 0.68 percent and the ash yield was 27.80 weight percent (db) (table 2). Because gas contents were low (fig. 4), the ash yields of the coal in the individual canisters and the total gas content (dafb) could not be determined. See tables A5 and A6 in appendix A for raw data. Canister 1 (WV-02-US4-5; 405.30-407.30 ft)—A total of 27 desorption measurements was taken from the coal over 23 days. The measured raw-total-gas content of the coal was 0.46 SCF/ton (0.01 cc/g). 5For this study, a 24-hour clock was used for reporting time.
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 15 Canister 2 (WV-02-B3-2; 407.30-408.00 ft)—A total of 6 desorption measurements was taken from the coal on September 30, 2002. A measured gas volume was recorded only on the second measurement. The measured raw-total-gas content of the coal was 0.57 SCF/ton (0.02 cc/g) (based on the single measurement). Gas chemistry of the Redstone coal bed.—There was insufficient gas from the Redstone coal bed canisters to ana lyze for chemical constituents. Pittsburgh Roof Coal Interval Throughout the northern Appalachian basin, the Pitts burgh roof coal interval (or sequence) typically consists of interbedded shale, mudstone, and thin coal beds that overlie the thick, minable Pittsburgh coal bed. In the Mylan Park study area, the roof interval above the Pittsburgh coal bed is 7.29 ft, of which 1.90 ft is coal. The interval was cored and retrieved from a depth of 426.96 to 433.85 ft at 17:52 hours on September 30, 2002. Only coal samples were desorbed: F g u r e
A
Ref e r to ap ti on F g u r e
B
Ref e r to ap ti on F g u r e
Ref e r to ap ti on F g u r e
D
Ref e r to ap ti on Figure 3. Graphs showing cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Sewickley coal bed plotted against the square root of time (in hours). Note the virtual absence of desorbed gas. Canister numbers and coal sample depths are shown. Because coal-bed gas migrates from coal during mining, these analyses should not be regarded as representative of the Sewickley coal bed in areas where it has not been previously mined. See tables A1, A2, A3, and A4 in appendix A for the desorption data from which these graphs were derived.
16 Coal and Petroleum Resources in the Appalachian Basin a 1-ft-long coal sample of the Pittsburgh roof coal interval from 426.96 to 427.96 ft and a 0.90-ft-long coal sample from 432.35 to 433.25 ft were placed in two 1-ft-long PVC canis ters (fig. 5). The measured raw-total-gas content of the coals from the sampled portion of the Pittsburgh roof coal interval (using a weighted average) was 1.25 SCF/ton (0.04 cc/g). The overall moisture content was 1.63 percent and the ash yield was 83.05 weight percent (db) (table 2). The total gas content (dafb) could not be determined because the ash yield of coal from the Pittsburgh roof coal interval was not determined. See tables A7 and A8 in appendix A for raw data. Canister 1 (WV-02-B3-3, 426.96-427.96 ft)—A total of 30 desorption measurements was taken from the coal over 26 days (fig. 5). The measured raw-total-gas content of the coal was 1.29 SCF/ton (0.04 cc/g). Canister 2 (WV-02-B3-5; 432.35-433.25 ft)—A total of 40 desorption measurements was taken from the coal over 38 days. The measured raw-total-gas content of the coal was 1.20 SCF/ton (0.04 cc/g). Gas chemistry of the Pittsburgh roof coal interval.—A single gas sample was analyzed from the coal in the Pittsburgh roof coal interval (table 5). It contained only about 7 percent methane, even after correcting for air contamination (table 6). Although air contamination could have occurred in the gas sampling procedure, the low gas content is more likely attributed to a significant migration of gas out of the Pittsburgh roof coal interval and into the underlying void spaces within the mined Pittsburgh coal bed. In addition, some of the gas from the coals in the Pittsburgh roof coal interval could have migrated upward and escaped into the mined Sewickley coal bed. Pittsburgh Coal Bed (Mined) An 8.75-ft-long coal pillar from an abandoned Pittsburgh coal bed mine was cored and retrieved to the surface from a depth of 433.85 to 442.35 ft at 17:52 hours on September 30, 2002, and placed in four 2-ft-long, 4-inch-diameter aluminum canisters and one 1-ft-long PVC canisters for desorption. Desorption measurements were taken from each canister over 12 days (fig. 6). The measured raw-total-gas content of the Pittsburgh coal bed (using a weighted average) at Mylan Park was 1.0 SCF/ton (0.03 cc/g). The overall moisture content of the coal was 0.52 percent and the ash yield was 9.84 weight percent (db) (table 2). The ash yields of the coals within the five individual canisters were not determined, thus the total gas content (dafb) was not determined. See tables A9, A10, A11, A12, and A13 in appendix A for raw data. Canister 1 (WV-02-B3-4; 433.85-434.35 ft)—A total of 15 desorption measurements was taken from the coal (fig. 6). The measured raw-total-gas content of the coal was 0.53 SCF/ton (0.02 cc/g). Canister 2 (WV-02-US4-30; 434.35-436.35 ft)—A total of 14 desorption measurements was taken from the coal. The measured raw-total-gas content of the coal was 0.29 SCF/ton (0.01 cc/g). F gu re A - R e fe r to ap tion Fig ure 4B Ref er to Cap tio n Figure 4. Graphs showing cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Redstone coal bed plotted against the square root of time (in hours). Virtually no gas was emitted. The canister numbers and coal sample depths are shown. See tables A5 and A6 in appendix A for the desorption data from which these graphs were derived.
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 17 F gu re A Ref e r to ap ti on F gu re B Re fer
to ap ti on Figure 5. Graphs showing cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Pittsburgh roof coal interval plotted against the square root of time (in hours). The canister numbers and coal sample depths are shown. Because coal-bed gas migrates from coal during mining, these analyses should not be regarded as representative of the coals from the Pittsburgh roof coal interval in the area where the Sewickley and (or) Pittsburgh coal beds (higher or lower in the section, respectively) have not been previously mined. See tables A7 and A8 in appendix A for the desorption data from which these graphs were derived. Canister 3 (WV-02-US4-14; 436.35-438.35 ft)—A total of 14 desorption measurements was taken from the coal. The measured raw-total-gas content of the coal was 0.52 SCF/ton (0.02 cc/g). Canister 4 (WV-02-US4-8; 438.35-440.35 ft)—A total of 14 desorption measurements was taken from the coal. The measured raw-total-gas content of the coal was 0.36 SCF/ton (0.01 cc/g). Canister 5 (WV-02-US4-6; 440.35-442.35 ft)—A total of 14 desorption measurements was taken from the coal. The measured raw-total-gas content of coal was 0.73 SCF/ton (0.02 cc/g). Gas chemistry of the Pittsburgh coal bed.—Because the Pittsburgh coal bed had been mined in this location, there was little desorbed gas. Three coal-bed-gas samples from the Pittsburgh coal bed were analyzed for gas chemistry (table 5) and the results were recalculated to an air-free basis (table 6). Only one sample (sample 46862 taken on October 11, 2002) contained abundant methane (about 79 percent) on an air-free basis. Little Pittsburgh Coal Bed A total of 0.75 ft of coal from the Little Pittsburgh coal bed was cored and retrieved to the surface from a depth of 468.50 to 469.50 ft at 13:48 hours on October 1, 2002, and placed into a 1-ft-long PVC canister. A total of 47 desorption measurements was taken over 64 days (fig. 7). The measured raw-total-gas content of the coal bed (using a weighted average) was 13.52 SCF/ton (0.42 cc/g). The overall moisture content was 1.15 percent and the ash yield of the coal was 43.69 weight percent (db) (table 2). The total gas content (dafb) was 25.44 SCF/ton (0.79 cc/g). See table A14 in appendix A for raw data. Gas chemistry of the Little Pittsburgh coal bed.—Two coal-bed-gas samples from the Little Pittsburgh coal bed were analyzed (table 5) and recalculated to an air-free basis (table 6). Both samples were contaminated by air to varying degrees, either through the gas sampling procedure or by interaction with air from mining in the overlying Pittsburgh coal bed. Sample DOE-MP No. 11 contained 47 percent methane (on an air-free basis) (table 6); the second sample did not confirm the presence of methane after recalculation.
18 Coal and Petroleum Resources in the Appalachian Basin F g u r e 6A R ef er t o Ca pt io n F g u r e 6B R ef er t o Ca pt io n F g u r e R ef er t o Ca pt io n F g u r e 6D R ef er t o Ca pt io n F g u r e 6E R ef er t o Ca pt io n Figure 6. Graphs showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Pittsburgh coal bed plotted against the square root of time (in hours). No gas was expected as the coal was drilled from a pillar in an abandoned mine. The canister numbers and coal sample depths are shown. Because coal-bed gas migrates from coal during mining, these analyses should not be regarded as representative of the Pittsburgh coal bed in areas where it has not been previously mined. See tables A9, A10, A11, A12, and A13 in appendix A for the desorption data from which these graphs were derived.
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 19 Elk Lick Coal Bed A 0.67-ft-long sample of coal from the Elk Lick coal bed was cored and retrieved to the surface from a depth of 659.93 to 660.60 ft and placed into a 1-ft-long PVC canister (WV- 02-B3-6) at 15:20 hours on October 1, 2002, for desorption. A total of 78 desorption measurements was taken over 431 days. The gas desorption profile (fig. 8) shows that gas continued to be released from the coal when the experiment was halted because of time constraints. The measured lost gas for the Elk Lick coal bed was 60 cc, the highest lost gas volume in this study. The measured raw-total-gas content of the coal bed (using a weighted average) was 62.68 SCF/ton (1.96 cc/g). The overall moisture content of the coal was 0.85 percent and the ash yield was 24.3 weight percent (db) (table 2). The total gas content (dafb) was 82.88 SCF/ton (2.59 cc/g). See table A15 in appendix A for raw data. Gas chemistry of the Elk Lick coal bed.—Four gas sam ples from the Elk Lick coal bed were analyzed (table 5) and recalculated to an air-free basis (table 6). All of the samples had high nitrogen contents. Sample 60587 had a very low methane content (<1 percent on an air-free basis). Samples DOE-MP No. 4, DOE-MP No. 6, and DOE-MP No. 12 had methane contents ranging from 82 to 87 percent (on an air-free basis) (table 6). F gu re R ef er t o apt ion Figure 7. Graph showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal sample from the Little Pittsburgh coal bed plotted against the square root of time (in hours). The canister number and coal sample depth is shown. See table A14 in appendix A for the desorption data from which this graph was derived. F ig ur e Ref e r t o C apt ion Figure 8. Graph showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal sample from the Elk Lick coal bed plotted against the square root of time (in hours). The canister number and coal sample depth is shown. See table A15 in appendix A for the desorption data from which this graph was derived. Brush Creek Coal Bed A 1.4-ft-long sample of coal from the Brush Creek coal bed was cored and retrieved to the surface from a depth of 920.40 to 921.80 ft at 17:46 hours on October 7, 2002, and placed into two 1-ft-long PVC canisters for desorption. Gas continued to be released from the coal when the experiment was halted 425 days later because of time constraints (fig. 9). There was no measured lost gas for the Brush Creek coal bed. The measured raw-total-gas content of the coal bed (using a weighted average) was 67.38 SCF/ton (2.11 cc/g) (dafb). The overall moisture content of the coal was 0.95 percent and the ash yield was 43.43 weight percent (db) (table 2). The total gas content (dafb) was 67.38 SCF/ton (2.11 cc/g). See tables A16 and A17 in appendix A for raw data. Canister 1 (WV-02-B3-7; 920.40-921.10 ft)—A total of 78 desorption measurements was taken from the coal over 425 days. The measured raw-total-gas content was 40.97 SCF/ton (1.28 cc/g). The moisture content of the coal was 1.10 percent, the ash yield of the coal was 62.67 weight percent (db), and the total gas content (dafb) was 112.64 SCF/ton (3.52 cc/g). Canister 2 (WV-02-B3-8; 921.10-921.80 ft)—A total of 83 desorption measurements was taken from
20 Coal and Petroleum Resources in the Appalachian Basin the coal over 425 days. The measured raw-total-gas content was 107.09 SCF/ton (3.35 cc/g). The moisture content of the coal was 0.90 percent, the ash yield was 12.34 weight percent (db), and the total gas content (dafb) was 122.14 SCF/ton (3.82 cc/g). Gas chemistry of the Brush Creek coal bed.—Three coalbed-gas samples from the Brush Creek coal bed were analyzed (table 5) and recalculated to an air-free basis (table 6). The methane contents of the samples ranged from 84 to 98 percent (on an air-free basis) (table 6). Upper Kittanning Coal Bed A 1.70-ft-long coal sample from the Upper Kittanning coal bed was cored and retrieved to the surface from a depth of 1,121.70 to 1,123.40 ft at 9:05 hours on October 9, 2002, and placed in two 1-ft-long PVC canisters. A total of 82 desorption measurements was taken over 424 days for each canister (fig. 10). The measured raw-total-gas content (using a weighted average) was 130.98 SCF/ton (4.09 cc/g). The overall moisture content of the coal in the two canisters was 0.97 percent and the ash yield was 9.25 weight percent (db) (table 2). The total gas content (dafb) was 142.25 SCF/ton (4.45 cc/g). See tables A18 and A19 in appendix A for raw data. Canister 1 (WV-02-B3-9; 1,121.70-1,122.70 ft)—The measured raw-total-gas content of the coal was 136.33 SCF/ton (4.26 cc/g). The moisture content was 1.07 percent, the ash yield was 6.65 weight percent (db), and the total gas content (dafb) was 146.14 SCF/ton (4.57 cc/g). Canister 2 (WV-02-B3-10; 1,122.70-1,123.40 ft)—The measured raw-total-gas content was 123.34 SCF/ton (3.85 cc/g). The moisture content was 1.24 percent, the ash yield was 12.55 weight percent (db), and the total gas content (dafb) was 140.77 SCF/ton (4.40 cc/g). Gas chemistry of the Upper Kittanning coal bed.—Four coal-bed-gas samples from the Upper Kittanning coal bed were analyzed (table 5) and recalculated to an air-free basis (table 6). Even after correcting for air, the nitrogen contents were relatively high, ranging from 4 to almost 10 percent (table 6). The methane contents for two individual canisters (WV-02-B3-9 and WV-02-B3-10) and for the cumulative coal bed sample ranged from 83 to 95 percent (on an air-free basis) (table 6). Middle Kittanning Coal Zone A 3.75-ft-thick sample of coal from two splits of the Middle Kittanning coal zone was cored and retrieved to the surface in two runs from a depth of 1,184.10 to 1,190.45 ft at 13:38 and 13:31 hours on October 9, 2002, and placed in five 1-ft-long PVC canisters. A total of 78 or 79 desorption measurements was taken over 424 days and gas continued F ig ur e 9A Ref e r t o C apt ion F ig ur e 9B Ref e r t o C apt ion Figure 9. Graphs showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Brush Creek coal bed plotted against the square root of time (in hours). The canister numbers and coal sample depths are shown. Note the differences in the amount of gas released from the coal in the two samples. Canister 1 contained bony coal and dark-gray shale, whereas canister 2 contained comparatively purer coal. See tables A16 and A17 in appendix A for the desorption data from which these graphs were derived.
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 21 F ig ur e -A - R e fer to C aptio n F ig ur e -B - R e fer to C aptio n Figure 10. Graphs showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Upper Kittanning coal bed plotted against the square root of time (in hours). The canister numbers and coal sample depths are shown. See tables A18 and A19 in appendix A for the desorption data from which these graphs were derived. to be released from the coal when the experiment was halted (fig. 11) due to project time constraints. The measured rawtotal-gas content (using a weighted average) was 113.54 SCF/ton (3.59 cc/g). The overall moisture content of coals from the Middle Kittanning coal zone was 0.52 percent and the ash yield was 18.61 weight percent (db) (table 2). The total gas content (dafb) was 138.94 SCF/ton (4.40 cc/g). Estimated lost gas for the five canisters ranged from 0 to 40 cc. See tables A20, A21, A22, A23, and A24 in appendix A for raw data. Canister 1 (WV-02-B3-11; 1,184.10-1,185.10 ft)—A total of 78 desorption measurements was taken from the coal over 424 days. The measured raw-total-gas content of the coal in the canister was 95.36 SCF/ton (2.98 cc/g). The moisture content was 0.65 percent, the ash yield was 21.18 weight percent (db), and the total gas content (dafb) was 121.03 SCF/ton (3.78 cc/g). This canister had 20 cc of estimated lost gas. Canister 2 (WV-02-CB3-12; 1,185.10-1,185.40 ft)—A total of 78 desorption measurements was taken from the coal over 424 days. The measured raw-totalgas content of the coal in the canister was 103.42 SCF/ton (3.23 cc/g). The moisture content was 0.82 percent, the ash yield was 29.10 weigh percent (db), and the total gas content (dafb) was 146.14 SCF/ton (4.57 cc/g). This canister had 20 cc of estimated lost gas. Canister 3 (WV-02-B3-12; 1,188.00-1,189.00 ft)—A total of 78 desorption measurements was taken from the coal over 424 days. The measured raw-total-gas content of the coal was 104.81 SCF/ton (3.28 cc/g). The moisture content was 0.62 percent, the ash yield was 29.10 weight percent (db), and the total gas content (dafb) was 139.31 SCF/ton (4.35 cc/g). This canister had 40 cc of estimated lost gas. Canister 4 (WV2-02-B3-13; 1,189.00-1,190.00 ft)—A total of 79 desorption measurements was taken from the coal over 424 days. The measured raw-totalgas content of the coal was 138.96 SCF/ton (4.34 cc/g). The moisture content was 0.75 percent, the ash yield was 24.73 weight percent, and the total gas content (dafb) was 150.78 SCF/ton (4.71 cc/g). This canister had no estimated lost gas. Canister 5 (WV-02-CB3-11; 1,190.00-1,190.45 ft)—A total of 78 desorption measurements was taken from the coal over 424 days. The measured raw-totalgas content of the coal was 124.19 SCF/ton (3.88 cc/g). The moisture content was 0.88 percent, the ash yield was 16.34 percent (db), and the total gas content (dafb) was 148.61 SCF/ton (4.64 cc/g). This canister had 5 cc of lost gas. Gas chemistry of the Middle Kittanning coal zone.— The Middle Kittanning coal zone contains both an upper (1,184.10-1,185.40 ft) and a lower (1,188.00-1,190.45 ft) split, separated by a 2.60-ft-thick parting of interbedded shale and sandstone parting (Ruppert and others, 2004; West Virginia Geological and Economic Survey, 2007). Twelve coal-bed-gas samples were analyzed for the Middle Kittanning coal zone (table 5). The methane contents of the coals ranged from 68 to 94 percent (on an air-free basis) (table 6).
22 Coal and Petroleum Resources in the Appalachian Basin F ig ur e -A - R efer to Ca ption F ig ur e -B - R efer to Ca ption F ig ur e - R efer to Ca ption F ig ur e -D - R efer to Ca ption F ig ur e -E - R efer to Ca ption Figure 11. Graphs showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Middle Kittanning coal zone plotted against the square root of time (in hours). The canister numbers and coal sample depths are shown. See tables A20, A21, A22, A23, and A24 in appendix A for the desorption data from which these graphs were derived.
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 23 Clarion Coal Zone A 3.95-ft-long coal sample from the two splits of the Clarion coal zone was cored and retrieved to the surface from a depth of 1,270.50 to 1,280.80 ft on October 10, 2002. The top split (1,270.50-1,272.35 ft) was retrieved and placed in two 1-ft-long PVC canisters at 8:24 hours. The bottom split (1,278.70-1,280.80 ft) was retrieved in a second run and placed in two 1-ft-long PVC canisters at 10:28 hours. Gas continued to be released from canisters 1, 3, and 4 (samples WV-02-B3-14, WV-02-B3-16, and WV-02-B3-17, respectively) 423 days later (fig. 12) when they were opened. The coal in canister 2 (WV-02-B3-15) continued to desorb small amounts of gas until desorption ended 662 days later. The measured raw-total-gas content for coals from the Clarion coal zone (using a weighted average) was 85.69 SCF/ton (2.68 cc/g). The overall moisture content was 1.01 percent and the ash yield was 14.26 weight percent (db) (table 2). The total gas content (dafb) was 124.42 SCF/ton (3.89 cc/g). There was no estimated lost gas for any of the canisters. See tables A25, A26, A27, and A28 in appendix A for raw data. Canister 1 (WV-02-B3-14; 1,270.50-1,271.50 ft)—A total of 75 desorption measurements was taken over F ig ur e -A - R efer to Ca ption F ig ur e -B - R efer to Ca ption F ig ur e - R efer to Ca ption F ig ur e -B - R efer to Ca ption Figure 12. Graphs showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Clarion coal zone plotted against the square root of time (in hours). The canister numbers and coal sample depths are shown. See tables A25, A26, A27, and A28 in appendix A for the desorption data from which these graphs were derived.
24 Coal and Petroleum Resources in the Appalachian Basin 423 days. The measured raw-total-gas content was 49.14 SCF/ton (1.54 cc/g). The moisture content was 0.68 percent, the ash yield was 63.69 weight percent (db), and the total gas content (dafb) was 135.58 SCF/ton (4.24 cc/g). Canister 2 (WV-02-B3-15; 1,271.50-1,272.35 ft)—A total of 77 desorption measurements was taken over 662 days before gas finished desorbing. The measured raw-total-gas content was 70.52 SCF/ton (2.20 cc/g). The moisture content was 1.00 percent, the ash yield was 63.69 weight percent (db), and the total gas con tent (dafb) was 81.64 SCF/ton (2.55 cc/g). Canister 3 (WV-02-B3-16; 1,278.70-1,279.70 ft)—A total of 75 desorption measurements was taken over 423 days. The measured raw-total-gas content was 134.84 SCF/ton (4.21 cc/g). The moisture content was 0.67 percent, the ash yield was 10.84 weight percent (db), and the total gas content (dafb) was 151.15 SCF/ton (4.72 cc/g). Canister 4 (WV-02-B3-17; 1,279.70-1,280.80 ft)—A total of 75 desorption measurements was taken over 423 days. The measured raw-total-gas content was 125.35 SCF/ton (3.92 cc/g). The moisture content was 0.71 percent, the ash yield was 17.96 weight percent (db), and the total gas content (dafb) was 152.82 SCF/ton (4.78 cc/g). Gas chemistry of the Clarion coal zone.—Like the Middle Kittanning coal zone, the Clarion coal zone also contains both an upper (1,270.50-1,272.35 ft) and a lower (1,278.70-1,280.8 ft) split, separated by a 6.35-ft-thick part ing of interbedded shale, claystone, mudstone, and sandstone (Ruppert and others, 2004; West Virginia Geological and Eco nomic Survey, 2007). Four coal-bed-gas samples were ana lyzed for the upper split and four coal-bed-gas samples were analyzed for the lower split (table 5). The methane contents of coals from the upper split ranged from 75 to 94 percent (on an air-free basis) (table 6). The methane contents of the coals of the lower split ranged from 81 to 95 percent (on an air-free basis) (table 6). Upper Mercer Coal Bed A 0.75-ft-long coal sample from the Upper Mercer coal bed was cored and retrieved to the surface from a depth of 1,324.40 to 1,325.15 ft at 14:31 hours on October 10, 2002, and placed in a 1-ft-long PVC canister. A total of 71 desorp tion measurements was taken over 423 days (fig. 13) and gas continued to be released from the coal when the experiment was halted due to time constraints. The canister had 10 cc of estimated lost gas. The measured raw-total-gas content of coal from the Upper Mercer coal bed (using a weighted average) was 95.02 SCF/ton (2.97 cc/g). The overall moisture content was 0.72 percent, the ash yield was 10.94 weight percent (db) F ig ur e Ref er t o Ca ption Figure 13. Graph showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal sample from the Upper Mercer coal bed plotted against the square root of time (in hours). The canister number and coal sample depth is shown. See table A29 in appendix A for the desorption data from which this graph was derived. F ig ur e Ref er t o Ca pti on Figure 14. Graph showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal sample from the Lower Mercer coal bed plotted against the square root of time (in hours). The canister number and coal sample depth is shown. The higher ash yield (30.62 weight percent, dry basis) resulted in substantially lower gas volumes than the coal from the Upper Mercer coal bed (ash yield of 10.96 weight percent, dry basis) (table 2). See table A30 in appendix A for the desorption data from which this graph was derived. (table 2), and the total gas content (dafb) was 106.67 SCF/ton (3.33 cc/g). See table A29 in appendix A for raw data. Gas chemistry of the Upper Mercer coal bed.—Three coal-bed-gas samples from the Upper Mercer coal bed were analyzed (table 5) and recalculated to an air-free basis (table 6). Methane contents ranged from 86 to 93 percent (on an airfree basis) (table 6).
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 25 Lower Mercer Coal Bed A 1.00-ft-long coal sample from the Lower Mercer coal bed was cored and retrieved to the surface from a depth of 1,357.50 to 1,358.50 ft at 17:51 hours on October 10, 2002, and placed in a single PVC canister. A total of 86 desorption measurements was taken over 423 days and gas continued to be released from the coal when the experiment was halted due to time constraints (fig. 14). There was no estimated lost gas. The measured raw-total-gas content of the coal from the Lower Mercer coal bed (using a weighted average) was 35.27 SCF/ton (1.10 cc/g). The overall moisture content was 0.49 percent, the ash yield was 30.62 weight percent (db) (table 2), and the total gas content (dafb) was 50.84 SCF/ton (1.59 cc/g). See table A30 in appendix A for raw data. Gas chemistry of the Lower Mercer coal bed.—Three samples of the Lower Mercer coal-bed gas were analyzed (table 5) and recalculated to an air-free basis (table 6). Meth ane contents ranged from 66 to 93 percent (on an air-free basis) (table 6). Quakertown Coal Zone A 1.73-ft-long sample of coal from two splits of the Quakertown coal zone was cored and retrieved to the surface from a depth of 1,465.00 to 1,476.43 ft at 11:46 hours on October 15, 2002. The 0.3-ft-long sample of coal from the top of the top split was inadvertently placed in the core box and not desorbed. The remaining 1.43 ft of coal was placed in two 1-ft-long PVC canisters. A total of 71 desorption mea surements was taken over 418 days and gas continued to be released from the coal when the experiment was halted due to time constraints (fig. 15). The measured raw-total-gas content (weighted average) was 67.84 SCF/ton (2.12 cc/g). The over all moisture content of the coals was 0.82 percent and the ash yield was 35.37 weight percent (db) (table 2). The total gas content (dafb) was 88.17 SCF/ton (2.76 cc/g). See tables A31 and A32 in appendix A for raw data. Canister 1 (WV-02-B3-20; 1,465.00-1,465.60 ft)—The measured raw-total-gas content was 85.90 SCF/ton (2.68 cc/g). The moisture content was 1.05 percent, the ash yield was 33.48 percent, and the total gas content (dafb) was 75.65 SCF/ton (2.36 cc/g). Estimated lost gas for this canister was 10 cc. Canister 2 (WV-02-B3-21; 1,475.60-1,476.43 ft)—The measured raw-total-gas content was 50.33 SCF/ton (1.57 cc/g). The moisture content was 0.47 percent, the ash yield was 27.74 weight percent, and the total gas content (dafb) was 75.65 SCF/ton (2.36 cc/g). Estimated lost gas for this canister was 10 cc. Gas chemistry of the Quakertown coal zone.—Three coal-bed-gas samples from the Quakertown coal zone were analyzed (table 5) and recalculated to an air-free basis F ig ur e -A - R efer
to Cap tio n F ig ur e -B Refe r to Ca pti on Figure 15. Graphs showing the cumulative coal-bed-gas desorption volumes (in cubic centimeters, cc) of the coal samples from the Quakertown coal zone plotted against the square root of time (in hours). The canister numbers and coal sample depths are shown. See tables A31 and A32 in appendix A for the desorption data from which these graphs were derived. (table 6). Methane contents for the samples ranged from 86 to 99 percent (on an air-free basis) (table 6). Two of the gas samples, DOE-MP No. 23 (from canister WV-02-B2-20) and DOE-MP No. 22 (from canister WV-02-B3-21), which were analyzed by the DOE-NETL laboratory on October 15, 2002, contained high nitrogen contents (14 and 10 percent, respectively) after normalizing to an air-free basis (table 6). In contrast, a composite gas sample (sample 48348, table 6) that was taken about two weeks later and analyzed by Isotech Laboratories, Inc., contained no nitrogen. These differences are currently not explainable with available data.
26 Coal and Petroleum Resources in the Appalachian Basin Figu re - R efe r t o C apt ion Figure 16. Bernard diagram for Mylan Park coal-bed-gas samples (modified from Bernard and others, 1978; Faber and Stahl, 1984; Whiticar, 1994). This diagram plots the isotopic composition of carbon (carbon 13, 13C) in methane reported as the deviation in units (δ13C) of parts per thousand (per mil) relative to the Vienna Peedee belemnite (VPDB) standard against the ratio of methane (C1) to the sum of the higher molecular gases (C2+, which includes ethane, propane, iso-butane, n-butane, isopentane, 2-methylbutane, n-pentane, and hexane). The diagram shows that, with the exception of the Quakertown coal-bed-gas sample, methane from coal beds at the Mylan Park study area is thermogenic. Note that the coal-bed-gas sample from the Quakertown coal zone falls in the mixing zone, suggesting a mixed thermal and biogenic origin. Abbreviations are as follows: %Ro, percent vitrinite reflectance. Isotope Analyses The isotopic composition of methane was measured in selected samples throughout the desorption experiment. Coalbed-gas samples from the following coal beds and coal zones were analyzed: Pittsburgh, Brush Creek, Upper Kittanning, Middle Kittanning, Clarion, Upper Mercer, Lower Mercer, and Quakertown (table 4). The graph showing the isotopic composition of carbon in methane (reported as the deviation (expressed as δ13C) in units of parts per thousand (per mil) relative to the Vienna Peedee belemnite (VPDB) standard) plotted against the ratio of methane (C1) to the sum of the higher molecular gases (C2+) shows that methane from all of the coals beds or zones, with the exception of the Quakertown coal zone, is thermogenic in origin (figs. 16 and 17). Coal-bed gas from the Quakertown coal zone plots in the mixing or transitional zone, suggesting that it has been partially oxidized by microbial activity. Adsorption Results High-pressure carbon-dioxide-adsorption isotherms were analyzed on coals from the Upper Kittanning coal bed and the Middle Kittanning and Clarion coal zones to determine their maximum carbon-dioxide-sorption capacity as a function of pressure. Only three of the samples (canister 1, WV-02- B3-14; canister 3, WV-02-B3-16; and canister 4, WV-02- B3-17) from the Clarion coal zone were analyzed. (The coal in canister 2, WV-02-B3-15, from the Clarion coal zone was mislabeled in the field as a split of the Lower Kittanning coal bed. The correct correlation was made after opening the canis ter and comparing the coal to the electric log.)
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 27 Fig ure - R efe r t o C apt on Figure 17. Enlargement of the thermogenic sector of the Bernard diagram (fig. 16) showing where composite coal-bed-gas samples from entire coal beds and coal zones (for example, Pittsburgh, Brush Creek, Upper Kittanning, Middle Kittanning, Upper Mercer, and Quakertown coal beds and zones), individual canisters (for example, Clarion coal zone sample WV-02-CB3-14), or composite samples from one or two canisters from a single coal bed or coal zone (for example, Clarion coal zone samples WV-02-CB3-16 and WV-02- CB3-17; Middle Kittanning coal zone samples WV-02-CB3-12 and WV-02-CB3-13) plot on the diagram. As on figure 16, this diagram plots the isotopic composition of carbon (carbon 13, 13C) in methane (reported as the deviation in units (δ13C) of parts per thousand (per mil) relative to the Vienna Peedee belemnite (VPDB) standard) against the ratio of methane (C1) to the sum of the higher molecular gases (C2+, which includes ethane, propane, iso-butane, n-butane, iso-pentane, 2-methylbutane, n-pentane, and hexane). Abbreviations are as follows: %Ro, percent vitrinite reflectance.
28 Coal and Petroleum Resources in the Appalachian Basin The Upper Kittanning coal bed and Middle Kittanning and Clarion coal zones were chosen for high-pressure carbondioxide-adsorption isotherm analyses because the samples were relatively thick (1.7-3.95 ft), were retrieved from a deep part of the borehole (1,112.70-1,270.50 ft), and contained abundant gas (85.69-130.98 SCF/ton (dafb) or 2.68-4.09 cc/g). Methane adsorption analyses were not performed on the three coals because of cost considerations. However, Ronald W. Stanton (U.S. Geological Survey, unpub. data, 2001) and Gluskoter and others (2002) have shown that there is a direct relationship between the rank of the coal and its carbondioxide and methane adsorption (fig. 18). The diagram shown in figure 18 indicates that the high-volatile A bituminous coals from the Mylan Park study area can adsorb about twice as much carbon dioxide as methane. This relationship allowed us to estimate the maximum amount of methane that could be adsorbed onto the coals and the degree of methane saturation at reservoir pressures. Reservoir pressure was not measured in the Mylan Park borehole, so normal hydrostatic pressure was calculated by multiplying a constant for hydrostatic pressure per foot (0.433) by the depth to the coal. It is important to note we may have overestimated total reservoir pressure by using hydrostatic pressure because much of the northern Appalachian basin is known to be underpressured (Roen and Walker, 1996). Upper Kittanning Coal Bed The coals of the Upper Kittanning coal bed in the Mylan Park study area were calculated to have a hydrostatic pressure of 486 pounds per square inch of area (PSIA) based on a mean depth of 1,122.50 ft for the coal bed. This corresponds to a maximum carbon-dioxide adsorption of about 500 SCF/ton on an as-received basis (arb) (15.63 cc/g, arb) (fig. 19). On an as-received basis, the calculated Langmuir volume is 831.8 SCF/ton (24.45 cc/g), the Langmuir pressure is 327.1 PSIA, the moisture content is 1.84 percent, and the ash yield is 8.58 weight percent. Figure 19 also shows data on the following bases: (1) dry, ash-free; (2) as-received; and (3) ash-free, moisture included. The estimated maximum methane adsorp tion is approximately one half of the maximum carbon-dioxide adsorption (fig. 19), which corresponds to approximately 250 SCF/ton (7.81 cc/g) (arb), indicating that the Upper Kittanning Figure Re fe r to
a p t io n Figure 18. Graph showing the relation between carbon dioxide and methane variation with coal rank (modified from Gluskoter and others, 2002). On the basis of high-volatile A bituminous rank of the coals from Mylan Park (black square), the plot shows that the estimated ratio of carbon dioxide to methane is 2 to 1.
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 29 F igu re - R efe r t o C apt ion Figure 19. Graph showing the maximum carbon-dioxide (red line) and methane (solid black line) adsorption curves for coal samples from the Upper Kittanning coal bed (from 1,121.70 to 1,123.40 feet) in the Mylan Park borehole, on an as-received basis (arb). The calculated hydrostatic pressure of 486 pounds per square inch of area (PSIA) intersects the as-received carbon-dioxide isotherm at about 500 standard cubic feet per ton (SCF/ton) or 15.63 cubic centimeters per gram (cc/g), which is a measure of the maximum amount of carbon dioxide that can be adsorbed to coal from the Upper Kittanning coal bed. The maximum methane adsorption is approximately half of that, or about 250 SCF/ton (7.81 cc/g) (arb). coal bed is undersaturated in methane (measured raw-total-gas was 130.98 SCF/ton or 4.09 cc/g, arb). Middle Kittanning Coal Zone The Middle Kittanning coal zone is not as attractive as a repository of carbon dioxide as the Upper Kittanning coal bed. The coals of the Middle Kittanning coal zone were calculated to have a hydrostatic pressure of 514 PSIA based on a mean depth of 1,184.10 ft. This corresponds to a maximum carbondioxide adsorption of about 400 SCF/ton or 12.5 cc/g (arb) (fig. 20). On an as-received basis, the calculated Langmuir volume is 580.0 SCF/ton (17.05 cc/g ), the Langmuir pres sure is 253.6 PSIA, the moisture content is 1.96 percent, and the ash yield is 19.91 weight percent. Figure 20 also shows data on the following bases: (1) dry, ash-free; (2) as-received; and (3) ash-free, moisture included. The estimated maximum methane adsorption is approximately one half of the maximum carbon-dioxide adsorption (fig. 20), which corresponds to approximately 200 SCF/ton or 6.25 cc/g (arb), indicating that the Middle Kittanning coal zone coals in the Mylan Park study area also are undersaturated in methane (measured raw-totalgas was 113.54 SCF/ton or 3.59 cc/g, arb). Clarion Coal Zone The coals of the Clarion coal zone were calculated to have a hydrostatic pressure of 552 PSIA based on a mean depth of 1,271.50 ft. This depth corresponds to a maximum carbon-dioxide adsorption of about 300 SCF/ton or 9.38 cc/g (arb) (fig. 21). On an as-received basis, the calculated Lang muir volume is 449.4 SCF/ton (17.05 cc/g), the Langmuir pressure is 265.9 PSIA, the moisture content is 1.57 percent, and the ash yield is 26.57 weight percent. Figure 21 also shows data on the following bases: (1) dry, ash-free; (2) asreceived; and (3) ash-free, moisture included. The estimated maximum methane adsorption is approximately one half of the maximum carbon-dioxide adsorption (fig. 21), which corresponds to approximately 150 SCF/ton or 6.25 cc/g (arb), indicating that these Clarion coal zone coals are undersatu rated in methane (measured raw-total-gas was 86.69 SCF/ton or 3.89 cc/g, arb).
30 Coal and Petroleum Resources in the Appalachian Basin F igu re - R efe r t o C apt ion Figure 21. Graph showing the maximum carbon-dioxide (red line) and methane (solid black line) adsorption curves for coal samples from the Clarion coal zone (from 1,270.50 to 1,271.50 feet) in the Mylan Park borehole, on an as-received basis (arb). The calculated hydrostatic pressure of 552 pounds per square inch of area (PSIA) intersects the as-received carbon-dioxide isotherm at about 300 standard cubic feet per ton (SCF/ton) or 9.38 cubic centimeters per gram (cc/g), which is a measure of the maximum amount of carbon dioxide that can be adsorbed to coal from the Clarion coal zone. The maximum methane adsorption is approximately half of that, or about 150 SCF/ton (4.69 cc/g) (arb). F igu re - R efe r t o C apt ion Figure 20. Graph showing the maximum carbon-dioxide (red line) and methane (solid black line) adsorption curves for coal samples from the Middle Kittanning coal zone (from 1,184.10 to 1,190.45 feet) in the Mylan Park borehole, on an as-received basis (arb). The calculated hydrostatic pressure of 514 pounds per square inch of area (PSIA) intersects the as-received carbon-dioxide isotherm at about 400 standard cubic feet per ton (SCF/ton) or 12.5 cubic centimeters per gram (cc/g), which is a measure of the maximum amount of carbon dioxide that can be adsorbed to coal from the Middle Kittanning coal zone. The maximum methane adsorption is approximately half of that, or about 200 SCF/ton (6.15 cc/g) (arb).
Chapter G.3 Results of Coalbed-Methane Drilling, Mylan Park, Monongalia County, West Virginia 31 Conclusions The measured raw-total-gas contents for coals in the Mylan Park, W. Va., study area, range from 0.07 SCF/ton (0.00 cc/g) for the mined Sewickley coal bed to 130.98 SCF/ton (4.09 cc/g) for the Upper Kittanning coal bed. The total coal-bed-gas values are minimum values because residual gas, which can be significant, was not measured. In a companion study (Ruppert and others, this volume, chap. G.4), the measurement of residual gas resulted in increased total gas resources of up to 40 percent. The coal-bed-gas contents of the coal beds in the Mylan Park study area did not increase systematically with depth. All gas contents increased to the depth of the Upper Kittanning coal bed (1,121.70-1,123.40 ft) and then decreased to 113.54 SCF/ton (3.59 cc/g) for the Middle Kittanning coal zone, 85.69 SCF/ton (2.68 cc/g) for the Clarion coal zone, 95.02 SCF/ton (2.97 cc/g) for the Upper Mercer coal bed, 35.27 SCF/ton (1.10 cc/g) for the Lower Mercer coal bed, and 67.84 SCF/ton (2.12 cc/g) for the Quakertown coal zone. The gas contents had to be normalized to an air-free basis, despite efforts to prevent air contamination during gas sampling. The mean methane content of all of the coals in the Mylan Park study area was 79.45 percent (air-free basis). High-pressure carbon-dioxide-adsorption isotherms show that coals of the Upper Kittanning coal bed have a greater potential for carbon-dioxide sequestration than those from the Middle Kittanning and Clarion coal zones. The maximum amount of carbon dioxide that can be adsorbed to coals of the Upper Kittanning coal bed is about 500 SCF/ton or 15.36 cc/g (arb) at the calculated hydrostatic pressure of 486 PSIA, which is higher than 400 SCF/ton or 9.38 cc/g (arb) for the Middle Kittanning coal zone coals and 300 SCF/ton or 9.38 cc/g (arb) for the Clarion coal zone coals. The coals from individual coal beds and coal zones at the Mylan Park study area desorbed slowly, which may imply slow methane-resource production rates. References Cited Barker, C.E., Dallegge, T.A., and Clark, A.C., 2002, USGS coal desorption equipment and a spreadsheet for analysis of lost and total gas from canister desorption measurements: U.S. Geological Survey Open-File Report 02-496, available only online at http://pubs.usgs.gov/of/2002/ofr-02-496/. Bernard, B.B., Brooks, J.M., and Sackett, W.M., 1978, Light hydrocarbons in Recent Texas continental shelf and slope sediments: Journal of Geophysical Research, v. 83, no. C8, p. 4053-4061. Diamond, W.P., Irani, M.C., Aul, G.N., and Thimons, E.D., 1986, Instruments, techniques, and equipment, chapter 6 in Deul, Maurice, and Kim, A.G., eds., Methane control research—Summary of results, 1964-80: U.S. Bureau of Mines Bulletin 687, p. 79-93. Faber, E., and Stahl, W., 1984, Geochemical surface explora tion for hydrocarbons in North Sea: American Association of Petroleum Geologists Bulletin, v. 68, no. 3, p. 363-386. Gluskoter, Hal, Stanton, R.W., Flores, R.M., and Warwick, P.D., 2002, Adsorption of carbon dioxide and methane in low-rank coals and the potential for sequestration of carbon dioxide [abs.]: American Association of Petroleum Geolo gists, Annual Meeting Expanded Abstracts, v. 2002, p. 640. Gas Research Institute, 1995, A guide to determining coal bed gas content: Chicago, Ill., Gas Research Institute, p. 8.1-8.22. Kendall, Carol, and Caldwell, E.A., 1998, Fundamentals of isotope geochemistry, in Kendall, Carol, and McDonnell, J.J., eds., Isotope tracers in catchment hydrology: Amster dam, Netherlands, Elsevier, p. 51-86. Kim, A.G., and Kissell, F.N., 1986, Methane formation and migration in coalbeds, chapter 3 in Duel, Maurice, and Kim, A.G., eds., Methane control research—Summary of results, 1964-80: U.S. Bureau of Mines Bulletin 687, p. 18-25. Rice, C.L., Hiett, J.K., and Koozmin, E.D., 1994, Glossary of Pennsylvanian stratigraphic names, central Appalachian basin, in Rice, C.L., ed., Elements of Pennsylvanian stra tigraphy, central Appalachian basin: Geological Society of America Special Paper 294, p. 115-155. Roen, J.B., and Walker, B.J., eds., 1996, The atlas of major Appalachian gas plays: West Virginia Geological and Eco nomic Survey Report V-25, 201 p. Ruppert, L.F., Fedorko, Nick, Warwick, P.D., Grady, W.C., Crangle, R.D., Jr., and Britton, J.Q., 2004, Results of coal bed methane drilling, Mylan Park, Monongalia County, West Virginia, U.S. Geological Survey Open-File Report 2004-1402, 44 p., plus appendixes, available only online at http://pubs.usgs.gov/of/2004/1402/. Stricker, G.D., Flores, R.M., Ochs, A.M., and Stanton, R.W., 2000, Powder River coal-bed methane—The USGS role in investigating this ultimate clean coal by-product, in Pro ceedings, 27th International Technical Conference on Coal Utilization and Fuel Systems, Clearwater, Fla., March 2000: Gaithersburg, Md., Coal Technology Association, 12 p.
32 Coal and Petroleum Resources in the Appalachian Basin West Virginia Geological and Economic Survey, 2007, Unpublished well log in field book 306-061: West Virginia Geological and Economic Survey [on file at West Virginia Geological and Economic Survey, 1 Mont Chateau Road, Morgantown, WV 26508-8079]. Whiticar, M.J., 1994, Correlation of natural gases with their sources, in Magoon L.B., and Dow, W.G., eds., The petro leum system—From source to trap: American Association of Petroleum Geologists Memoir 60, p. 261-283. Yee, Dan, Seidle, J.P., and Hanson, W.B., 1993, Gas sorption on coal and measurement of gas content, in Law, B.E., and Rice, D.D., eds., Hydrocarbons from coal: American Asso ciation of Petroleum Geologists Studies in Geology, v. 38, p. 203-218.
Appendix A. Desorption Data for Coal Samples Retrieved From a Borehole at Mylan Park, Monongalia County, W. Va. The original data for each canister in this study may be accessed by clicking on the link below. The tables follow the terminology, abbreviations, and format of the data spreadsheets found in Barker and others (2002), which also contains a detailed discussion of their use; therefore, the terminology may not be identical to that found in the text of this report. Coal samples from indi vidual canisters from the Sewickley coal bed, Redstone coal bed, Pittsburgh coal roof interval, and Pittsburgh coal bed were not analyzed for ash content because the measured gas contents were very low; thus, dry, ash-free total gas content was not determined. See table headnotes for an explanation of abbreviations. CLICK HERE TO ACCESS APPENDIX A DATA