{"pageNumber":"132","pageRowStart":"3275","pageSize":"25","recordCount":10951,"records":[{"id":70146876,"text":"70146876 - 2014 - Continuous monitoring of Hawaiian volcanoes with thermal cameras","interactions":[],"lastModifiedDate":"2019-03-13T09:22:17","indexId":"70146876","displayToPublicDate":"2015-04-23T11:15:00","publicationYear":"2014","noYear":false,"publicationType":{"id":2,"text":"Article"},"publicationSubtype":{"id":10,"text":"Journal Article"},"seriesTitle":{"id":3841,"text":"Journal of Applied Volcanology","active":true,"publicationSubtype":{"id":10}},"title":"Continuous monitoring of Hawaiian volcanoes with thermal cameras","docAbstract":"

Continuously operating thermal cameras are becoming more common around the world for volcano monitoring, and offer distinct advantages over conventional visual webcams for observing volcanic activity. Thermal cameras can sometimes “see” through volcanic fume that obscures views to visual webcams and the naked eye, and often provide a much clearer view of the extent of high temperature areas and activity levels. We describe a thermal camera network recently installed by the Hawaiian Volcano Observatory to monitor Kīlauea’s summit and east rift zone eruptions (at Halema‘uma‘u and Pu‘u ‘Ō‘ō craters, respectively) and to keep watch on Mauna Loa’s summit caldera. The cameras are long-wave, temperature-calibrated models protected in custom enclosures, and often positioned on crater rims close to active vents. Images are transmitted back to the observatory in real-time, and numerous Matlab scripts manage the data and provide automated analyses and alarms. The cameras have greatly improved HVO’s observations of surface eruptive activity, which includes highly dynamic lava lake activity at Halema‘uma‘u, major disruptions to Pu‘u ‘Ō‘ō crater and several fissure eruptions.

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When all sites and parent materials were combined, soil texture was the most important factor predicting the occurrence of L + Mav, with cover positively associated with higher silt, very fine sand, and fine sand fractions and negatively associated with the very coarse sand fraction. 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The Appalachian basin is a mature basin containing abundant oil, gas, and coal resources. Its fossil-fuel-bearing strata range in age from Cambrian to Permian and extend over the States of New York, Pennsylvania, Maryland, Ohio, West Virginia, Virginia, Kentucky, Tennessee, Georgia, and Alabama. The basin has provided abundant fossil fuels to support the Nation’s economic growth for at least 150 years and U.S. Geological Survey (USGS) assessments suggest that substantial untapped resources remain. A merger of new and old geologic data and ideas is required to locate and extract those remaining resources.

\n

This chapter brings together abundant existing datasets in a common and integrated spatial format to advance our understanding of the distribution, geologic framework, burial history, and geochemical character of the basin’s oil, gas, and coal resources. These datasets support the information and findings in chapters B through G of this volume, which include (1) geologic cross sections, seismic profiles, and burial history models that document the depositional and structural framework of the basin; (2) assessments of Carboniferous coal-bed gas and Devonian shale gas; (3) studies about the distribution of oil, gas, and coal fields and the geochemistry of natural gas and oil; and (4) a history of fossil-fuel production in the basin.

\n

The data that supported these studies were refined and made more accessible using geographic information system (GIS) tools. The following types of data are included: (1) the bedrock geology of States included within the boundary of the Appalachian basin, (2) the locations of oil and gas wells and fields, (3) data produced for the National Oil and Gas Assessment, and (4) the stratigraphy, geochemistry, and production of coal. Data layers are available in shapefile and Zipped Keyhole Markup Language (KMZ) formats, which can be viewed using ArcGIS, Google Earth, or any software package that supports these data formats.

\n

Metadata for these datasets are available in HTML and XML formats. Metadata files contain information about the sources of data used to create the dataset, the creation process steps, the data quality, the geographic coordinate system and horizontal datum used for the dataset, the values of attributes used in the dataset table, information about the publication and the publishing organization, and other information that may be useful to the reader. All links in the metadata were valid at the time of compilation. Some of these links may no longer be valid. No attempt has been made to determine the new online location (if one exists) for the data.

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The Appalachian basin is the oldest and longest producing commercially viable petroleum-producing basin in the United States. Source rocks for reservoirs within the basin are located throughout the entire stratigraphic succession and extend geographically over much of the foreland basin and fold-and-thrust belt that make up the Appalachian basin. Major source rock intervals occur in Ordovician, Devonian, and Pennsylvanian strata with minor source rock intervals present in Cambrian, Silurian, and Mississippian strata.

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This study presents high-resolution gas chromatograms of oils and molecular and isotopic analyses of oil-associated gases from 17 wells producing in the Upper Cambrian to Lower Ordovician Knox Group, the Middle and Upper Ordovician Stones River Group, and the Upper Ordovician Trenton Limestone in the Cumberland overthrust sheet. The wells are located in the Ben Hur and Rose Hill fields in Lee County, Va., and in the Swan Creek field in Hancock and Claiborne Counties, Tenn. They produce oils typical of those from source rocks that are rich in Gloeocapsomorpha prisca (G. prisca) (Assemblage A-type kerogen). The Rose Hill oils appear to come from a source that contains a higher proportion of Assemblage A-type kerogen than the Ben Hur and Swan Creek oils. Extrapolation of the δ13C compositions of oil-associated gases to possible kerogen compositions gives estimates of -23 to -24 per mil within the range of isotopic compositions of known G. prisca source material. Gases produced from the Knox Group wells in the Swan Creek field are different from those in the Middle and Upper Ordovician reservoirs and come from a source with a broader range of isotopic values. Trends in isotopic and gasoline-range compositional parameters of the oils and associated gas isotopic and molecular compositions are most likely influenced by changes in local source depositional facies.

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2014 - Assessment of Appalachian basin oil and gas resources: Utica-Lower Paleozoic Total Petroleum System","interactions":[{"subject":{"id":70048890,"text":"pp1708G.10 - 2014 - Assessment of Appalachian basin oil and gas resources: Utica-Lower Paleozoic Total Petroleum System","indexId":"pp1708G.10","publicationYear":"2014","noYear":false,"chapter":"G.10","title":"Assessment of Appalachian basin oil and gas resources: Utica-Lower Paleozoic Total Petroleum System"},"predicate":"IS_PART_OF","object":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"id":1}],"isPartOf":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"lastModifiedDate":"2020-05-14T18:51:07.317706","indexId":"pp1708G.10","displayToPublicDate":"2015-04-02T10:00:00","publicationYear":"2014","noYear":false,"publicationType":{"id":18,"text":"Report"},"publicationSubtype":{"id":5,"text":"USGS Numbered Series"},"seriesTitle":{"id":331,"text":"Professional Paper","code":"PP","onlineIssn":"2330-7102","printIssn":"1044-9612","active":true,"publicationSubtype":{"id":5}},"seriesNumber":"1708","chapter":"G.10","title":"Assessment of Appalachian basin oil and gas resources: Utica-Lower Paleozoic Total Petroleum System","docAbstract":"

The Utica-Lower Paleozoic Total Petroleum System (TPS) in the Appalachian Basin Province is named for the Upper Ordovician Utica Shale, which is the source rock, and for multiple lower Paleozoic sandstone and carbonate units that are the important reservoirs. The total organic carbon (TOC) values for the Utica Shale are usually greater than 1 weight percent. TOC values ranging from 2 to 3 weight percent outline a broad, northeast-trending area that extends across western and southern Pennsylvania, eastern Ohio, northern West Virginia, and southeastern New York. The Utica Shale is characterized by type II kerogen, which is a variety of kerogen that is typically prone to oil generation. Conondont color-alteration index (CAI) isograds, which are based on samples from the Upper Ordovician Trenton Limestone (or Group), indicate that a pod of mature Utica Shale source rocks occupies most of the TPS.

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The following strata (in ascending stratigraphic order) are the most important reservoir rocks for oil and gas in the Utica-Lower Paleozoic TPS: (1) the Upper Cambrian Copper Ridge dolomite in Ohio; (2) the Upper Cambrian Rose Run sandstone in Ohio; (3) the Upper Ordovician Black River Limestone (or Group) and Trenton Limestone in New York, West Virginia, and Ohio; (4) the Lower Silurian “Clinton” sandstone, Medina sandstone, Medina Group sandstones, and Tuscarora Sandstone in Ohio, Pennsylvania, New York, and West Virginia; and (5) the Lower and Upper Silurian Lockport Dolomite (also known as the Newburg zone) in Ohio. Strata containing oil and gas reservoirs of secondary importance are sandstone reservoirs in the Upper Ordovician Queenston Shale in New York, the Upper Ordovician Bald Eagle Sandstone in Pennsylvania, and the Upper Silurian Williamsport Sandstone (also known as the Newburg sandstone) in West Virginia. The Upper Ordovician Utica Shale may be an important gas and oil(?) reservoir in the future. In about 2011, after this report was written, commercial natural gas and oil was discovered in the Utica Shale in eastern Ohio.

\n

Both conventional oil and gas resources and continuous (unconventional) gas resources are present in the UticaLower Paleozoic TPS. Conventional oil and gas resources in the Utica-Lower Paleozoic TPS were assessed by the U.S. Geological Survey (USGS) in 2002 in the following assessment units (AU): (1) the Lower Paleozoic Carbonates in Thrust Belt AU, (2) the Knox Unconformity AU, (3) the Black River-Trenton Hydrothermal Dolomite AU, and (4) the Lockport Dolomite AU. The total estimated undiscovered oil and gas resources for these four AUs, at a mean value, was about 46 million barrels of oil (MMBO) and about 3 trillion cubic feet of gas (TCFG), respectively. In contrast, continuous (unconventional) gas resources in the TPS were assessed by the USGS in 2002 in four AUs associated with the “Clinton” sandstone, Medina sandstone, Medina Group sandstones, Tuscarora Sandstone, and sandstones in the Queenston Shale. The total estimated undiscovered gas for these four AUs, at a mean value, was about 26.8 TCFG. A hypothetical Utica Shale AU for oil(?) and continuous gas is identified in this report. In 2012, the Utica Shale was recognized by the USGS as a continuous AU and was assessed by Kirschbaum and others (2012).

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Oil and gas fields in Silurian carbonate and sandstone reservoirs in the Appalachian basin probably originated from one or more of the following source rocks: (1) Upper Ordovician Utica Shale, (2) Middle to Upper Devonian black shale, and (3) Lower to Upper Silurian shale and carbonate units. In this reconnaissance study, selected Silurian shale and carbonate rocks in the subsurface of New York, Ohio, Pennsylvania, and West Virginia were analyzed for total organic carbon (TOC) content and Rock-Eval parameters to evaluate whether or not a Silurian total petroleum system exists in the Appalachian basin. A total of 308 samples were collected and analyzed for this investigation. Dark-gray to black shale and argillaceous carbonate intervals in the Salina Group (and equivalent units), Cabot Head Shale, Rochester Shale, Rose Hill Formation, Lockport Dolomite (or Group), and McKenzie Limestone (or Member) were prioritized for sampling and analysis.

\n

Twenty nine of the 308 samples analyzed had TOC values of 0.50 or greater that qualify them as a petroleum source rock. Also, 24 of the 29 samples (with TOC values of 0.50 or greater) had TOC values between 0.50 and less than 1.00 weight percent. Only 5 samples in the dataset are classified as good to very good source rocks (TOC values of 1.00 to 3.35 weight percent). The majority (n=18) of the 29 samples of potential source rocks with a TOC value of 0.5 or greater are located in the Upper Silurian Salina Group and equivalent Wills Creek Formation. Moreover, all of the good to very good source rocks are located in the Salina Group and Wills Creek Formation in southwestern Pennsylvania and northern West Virginia. The remainder (n=11) of the 29 potential source rocks (TOC values of 0.50 to less than 1.00 weight percent) are located in the Lower Silurian Cabot Head Shale (n=2), Rochester Shale (n=6), Rose Hill Formation (n=1), and Lower to Upper Silurian Lockport Dolomite (n=2). These source rocks of secondary importance are widely distributed across eastern Ohio, western Pennsylvania, and West Virginia.

\n

Although the TOC analyses in this study indicate that good to very good source rocks are present in the Salina Group and Wills Creek Formation of southwestern Pennsylvania and northern West Virginia, data are insufficient to propose a new Silurian total petroleum system in the Appalachian basin. However, the analytical results of this investigation are encouraging enough to undertake more systematic studies of the source rock potential of the Salina Group, Wills Creek Formation, and perhaps the Tonoloway Formation (Limestone) and McKenzie Limestone (or Member).

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This report presents the results of a U.S. Geological Survey (USGS) assessment of the technically recoverable undiscovered natural gas resources in Devonian shale in the Appalachian Basin Petroleum Province of the eastern United States. These results are part of the USGS assessment in 2002 of the technically recoverable undiscovered oil and gas resources of the province. This report does not use the results of a 2011 USGS assessment of the Devonian Marcellus Shale because the area considered in the 2011 assessment is much greater than the area of the Marcellus Shale described in this report. The USGS assessment in 2002 was based on the identification of six total petroleum systems, which include strata that range in age from Cambrian to Pennsylvanian. The Devonian gas shales described in this report are within the Devonian Shale-Middle and Upper Paleozoic Total Petroleum System, which extends generally from New York to Tennessee. This total petroleum system is divided into ten assessment units (plays), four of which are classified as conventional and six as continuous. The Devonian shales described in this report make up four of these continuous assessment units. The assessment results are reported as fully risked fractiles (F95, F50, F5, and the mean); the fractiles indicate the probability of recovery of the assessment amount. The products reported are oil, gas, and natural gas liquids. The mean estimates for technically recoverable undiscovered hydrocarbons in the four gas shale assessment units are 12,195.53 billion cubic feet (12.20 trillion cubic feet) of gas and 158.91 million barrels of natural gas liquids

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character"},"lastModifiedDate":"2020-05-14T18:54:20.819932","indexId":"pp1708G.8","displayToPublicDate":"2015-03-31T11:45:00","publicationYear":"2014","noYear":false,"publicationType":{"id":18,"text":"Report"},"publicationSubtype":{"id":5,"text":"USGS Numbered Series"},"seriesTitle":{"id":331,"text":"Professional Paper","code":"PP","onlineIssn":"2330-7102","printIssn":"1044-9612","active":true,"publicationSubtype":{"id":5}},"seriesNumber":"1708","chapter":"G.8","title":"Evidence for Cambrian petroleum source rocks in the Rome trough of West Virginia and Kentucky, Appalachian basin","docAbstract":"

A 130-foot-thick Cambrian black shale sampled from a core between 11,150 and 11,195 feet in the Exxon No. 1 Smith well in Wayne County, W. Va., has been identified as a good to very good source rock. The black shale is located in the Middle Cambrian Rogersville Shale of the Conasauga Group. Total organic carbon (TOC) values of four samples that range from 1.2 to 4.4 weight percent (average 2.6 weight percent) are the highest reported to date in the pre-Knox section of the Rome trough. Although the samples are probably in the zone of gas generation based on their low hydrogen index values (55 to 63) and temperature maximum of second hydrocarbon peak (S2) values of about 465°C, first hydrocarbon peak (S1) values of 0.81 to 2.71 indicate that they contain free extractable hydrocarbons. A bitumen sample extracted from the Rogersville Shale is characterized by (1) a broad spectrum of n-alkanes from n-C11 through n-C30, (2) strong odd-carbon predominance in the n-C13 to n-C19 range, and (3) small but detectable amounts of isoprenoids pristane and phytane. The strong odd-carbon predominance of the n-C15 to n-C19 n-alkanes is commonly attributed to the Ordovician alga Gloeocapsomorpha prisca. This occurrence of G. prisca is among the first to be reported in Cambrian rocks. Thin black shale beds collected from the Lower to Middle Cambrian Rome Formation in the Texaco No. 1 Kirby well in Garrard County, Ky., have TOC values as high as 3.2 percent, hydrogen index values as high as 417, and bitumen extract characteristics similar to the Rogersville Shale.

\n

The bitumen extract from the Rogersville Shale compares very closely with oils or condensates from Cambrian reservoirs in the Carson Associates No. 1 Kazee well, Homer gas field, Elliott County, Ky.; the Inland No. 529 White well, Boyd County, Ky.; and the Miller No. 1 well, Wolfe County, Ky. These favorable oil-source rock correlations suggest a new petroleum system in the Appalachian basin that is characterized by a Conasauga Group source rock and Rome Formation and Conasauga Group reservoirs. This petroleum system probably extends along the Rome trough from eastern Kentucky to at least central West Virginia.

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Composition of natural gas and crude oil produced from 10 wells in the Lower Silurian \"Clinton\" Sandstone, Trumbull County, Ohio","indexId":"pp1708G.7","publicationYear":"2014","noYear":false,"chapter":"G.7","title":"Composition of natural gas and crude oil produced from 10 wells in the Lower Silurian \"Clinton\" Sandstone, Trumbull County, Ohio"},"predicate":"IS_PART_OF","object":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"id":1}],"isPartOf":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in 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Natural gases and associated crude oils in the “Clinton” sandstone, Medina Group sandstones, and equivalent Tuscarora Sandstone in the northern Appalachian basin are part of a regional, continuous-type or basin-centered accumulation. The origin of the hydrocarbon charge to regional continuoustype accumulations is poorly understood. We have analyzed the molecular and stable isotopic composition of gases and oils produced from 10 wells in the “Clinton” sandstone in Trumbull County, Ohio, in an initial attempt to identify the characteristics of the accumulated fluids. The analyses show that the fluids have remarkably uniform compositions that are similar to previously published analyses of oils (Cole and others, 1987) and gases (Laughrey and Baldasarre, 1998) in Early Silurian reservoirs elsewhere in Ohio; however, geochemical parameters in the oils and gases suggest that the fluids have experienced higher levels of thermal stress than the present-day burial conditions of the reservoir rocks. The crude oils have an unusual geochemical characteristic: they do not contain detectable levels of sterane and triterpane biomarkers. The origin of these absences is unknown.

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2014 - Composition of natural gas and crude oil produced from 14 wells in the Lower Silurian \"Clinton\" Sandstone and Medina Group Sandstones, northeastern Ohio and northwestern Pennsylvania","interactions":[{"subject":{"id":70048880,"text":"pp1708G.6 - 2014 - Composition of natural gas and crude oil produced from 14 wells in the Lower Silurian \"Clinton\" Sandstone and Medina Group Sandstones, northeastern Ohio and northwestern Pennsylvania","indexId":"pp1708G.6","publicationYear":"2014","noYear":false,"chapter":"G.6","title":"Composition of natural gas and crude oil produced from 14 wells in the Lower Silurian \"Clinton\" Sandstone and Medina Group Sandstones, northeastern Ohio and northwestern Pennsylvania"},"predicate":"IS_PART_OF","object":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"id":1}],"isPartOf":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"lastModifiedDate":"2020-05-14T18:57:10.012551","indexId":"pp1708G.6","displayToPublicDate":"2015-03-31T11:00:00","publicationYear":"2014","noYear":false,"publicationType":{"id":18,"text":"Report"},"publicationSubtype":{"id":5,"text":"USGS Numbered Series"},"seriesTitle":{"id":331,"text":"Professional Paper","code":"PP","onlineIssn":"2330-7102","printIssn":"1044-9612","active":true,"publicationSubtype":{"id":5}},"seriesNumber":"1708","chapter":"G.6","title":"Composition of natural gas and crude oil produced from 14 wells in the Lower Silurian \"Clinton\" Sandstone and Medina Group Sandstones, northeastern Ohio and northwestern Pennsylvania","docAbstract":"

The geochemical processes that control the distribution of hydrocarbons in the regional accumulation of natural gas and crude oil in reservoirs of Early Silurian age in the central Appalachian basin are not well understood. Gas and oil samples from 14 wells along a down-dip transect through the accumulation in northeastern Ohio and northwestern Pennsylvania were analyzed for molecular and stable isotopic compositions to look for evidence of hydrocarbon source, thermal maturation, migration, and alteration parameters. The correlation of carbon and hydrogen stable isotopic composition of methane with thermal maturation indicates that the deepest gases are more thermally mature than independent estimates of thermal maturity of the reservoir horizon based on the conodont alteration index. This correlation indicates that the natural gas charge in the deepest parts of the regional accumulation sampled in this study originated in deeper parts of the Appalachian basin and migrated into place. Other processes, including mixing and late-stage alteration of hydrocarbons, may also impact the observed compositions of natural gases and crude oils.

","largerWorkType":{"id":18,"text":"Report"},"largerWorkTitle":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character (Professional Paper 1708)","largerWorkSubtype":{"id":5,"text":"USGS Numbered Series"},"language":"English","publisher":"U.S. Geological Survey","publisherLocation":"Reston, VA","doi":"10.3133/pp1708G.6","usgsCitation":"Burruss, R.A., and Ryder, R., 2014, Composition of natural gas and crude oil produced from 14 wells in the Lower Silurian \"Clinton\" Sandstone and Medina Group Sandstones, northeastern Ohio and northwestern Pennsylvania: U.S. Geological Survey Professional Paper 1708, iv, 38 p., https://doi.org/10.3133/pp1708G.6.","productDescription":"iv, 38 p.","numberOfPages":"42","onlineOnly":"Y","additionalOnlineFiles":"N","ipdsId":"IP-007446","costCenters":[{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true}],"links":[{"id":299202,"type":{"id":24,"text":"Thumbnail"},"url":"https://pubs.usgs.gov/thumbnails/usgs_thumb.jpg"},{"id":299200,"type":{"id":11,"text":"Document"},"url":"https://pubs.usgs.gov/pp/1708/g6/pdf/pp1708_g6.pdf","text":"Report","size":"1.45 MB","linkFileType":{"id":1,"text":"pdf"},"description":"Report"}],"country":"United States","state":"Ohio, Pennsylvania","otherGeospatial":"Appalachian basin","geographicExtents":"{\n \"type\": \"FeatureCollection\",\n \"features\": [\n {\n \"type\": \"Feature\",\n \"properties\": {},\n \"geometry\": {\n \"type\": \"Polygon\",\n \"coordinates\": [\n [\n [\n -80.48721313476562,\n 40.88444793903562\n ],\n [\n -80.7879638671875,\n 41.01099329360268\n ],\n [\n -81.36474609375,\n 41.43449030894922\n ],\n [\n -81.3812255859375,\n 41.7180304600481\n ],\n [\n -81.199951171875,\n 41.77336007442078\n ],\n [\n -80.48309326171875,\n 41.51269075845857\n ],\n [\n -79.5355224609375,\n 41.66265316924903\n ],\n [\n -79.51904296874999,\n 40.88444793903562\n ],\n [\n -80.48721313476562,\n 40.88444793903562\n ]\n ]\n ]\n }\n }\n ]\n}","publishingServiceCenter":{"id":9,"text":"Reston PSC"},"noUsgsAuthors":false,"publicationStatus":"PW","scienceBaseUri":"551bb71be4b0323842783a28","contributors":{"editors":[{"text":"Ruppert, Leslie F. 0000-0002-7453-1061 lruppert@usgs.gov","orcid":"https://orcid.org/0000-0002-7453-1061","contributorId":660,"corporation":false,"usgs":true,"family":"Ruppert","given":"Leslie","email":"lruppert@usgs.gov","middleInitial":"F.","affiliations":[{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true},{"id":245,"text":"Eastern Mineral and Environmental Resources Science Center","active":true,"usgs":true}],"preferred":true,"id":543769,"contributorType":{"id":2,"text":"Editors"},"rank":1},{"text":"Ryder, Robert T.","contributorId":77918,"corporation":false,"usgs":true,"family":"Ryder","given":"Robert T.","affiliations":[],"preferred":false,"id":543770,"contributorType":{"id":2,"text":"Editors"},"rank":2}],"authors":[{"text":"Burruss, Robert A. 0000-0001-6827-804X burruss@usgs.gov","orcid":"https://orcid.org/0000-0001-6827-804X","contributorId":558,"corporation":false,"usgs":true,"family":"Burruss","given":"Robert","email":"burruss@usgs.gov","middleInitial":"A.","affiliations":[{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true}],"preferred":false,"id":542894,"contributorType":{"id":1,"text":"Authors"},"rank":1},{"text":"Ryder, Robert T.","contributorId":77918,"corporation":false,"usgs":true,"family":"Ryder","given":"Robert T.","affiliations":[],"preferred":false,"id":542893,"contributorType":{"id":1,"text":"Authors"},"rank":2}]}} ,{"id":70055614,"text":"pp1708G.5 - 2014 - Appalachian basin bituminous coal: sulfur content and potential sulfur dioxide emissions of coal mined for electrical power generation","interactions":[{"subject":{"id":70055614,"text":"pp1708G.5 - 2014 - Appalachian basin bituminous coal: sulfur content and potential sulfur dioxide emissions of coal mined for electrical power generation","indexId":"pp1708G.5","publicationYear":"2014","noYear":false,"chapter":"G.5","title":"Appalachian basin bituminous coal: sulfur content and potential sulfur dioxide emissions of coal mined for electrical power generation"},"predicate":"IS_PART_OF","object":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"id":1}],"isPartOf":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"lastModifiedDate":"2020-05-14T18:58:34.192557","indexId":"pp1708G.5","displayToPublicDate":"2015-03-31T10:45:00","publicationYear":"2014","noYear":false,"publicationType":{"id":18,"text":"Report"},"publicationSubtype":{"id":5,"text":"USGS Numbered Series"},"seriesTitle":{"id":331,"text":"Professional Paper","code":"PP","onlineIssn":"2330-7102","printIssn":"1044-9612","active":true,"publicationSubtype":{"id":5}},"seriesNumber":"1708","chapter":"G.5","title":"Appalachian basin bituminous coal: sulfur content and potential sulfur dioxide emissions of coal mined for electrical power generation","docAbstract":"

Data from 157 counties in the Appalachian basin of average sulfur content of coal mined for electrical power generation from 1983 through 2005 show a general decrease in the number of counties where coal mining has occurred and a decrease in the number of counties where higher sulfur coals (>2 percent sulfur) were mined. Calculated potential SO2 emissions (assuming no post-combustion SO2 removal) show a corresponding decrease over the same period of time.

","largerWorkType":{"id":18,"text":"Report"},"largerWorkTitle":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character (Professional Paper 1708)","largerWorkSubtype":{"id":5,"text":"USGS Numbered Series"},"language":"English","publisher":"U.S. Geological Survey","publisherLocation":"Reston, VA","doi":"10.3133/pp1708G.5","usgsCitation":"Trippi, M.H., Ruppert, L.F., Attanasi, E., Milici, R.C., and Freeman, P., 2014, Appalachian basin bituminous coal: sulfur content and potential sulfur dioxide emissions of coal mined for electrical power generation: U.S. Geological Survey Professional Paper 1708, iv, 68 p., https://doi.org/10.3133/pp1708G.5.","productDescription":"iv, 68 p.","numberOfPages":"72","onlineOnly":"Y","additionalOnlineFiles":"N","ipdsId":"IP-011829","costCenters":[{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true}],"links":[{"id":299196,"type":{"id":24,"text":"Thumbnail"},"url":"https://pubs.usgs.gov/thumbnails/usgs_thumb.jpg"},{"id":299195,"type":{"id":11,"text":"Document"},"url":"https://pubs.usgs.gov/pp/1708/g5/pdf/pp1708_g5.pdf","text":"Report","size":"8.51 MB","linkFileType":{"id":1,"text":"pdf"},"description":"Report"}],"country":"United States","otherGeospatial":"Appalachian basin","geographicExtents":"{\n \"type\": \"FeatureCollection\",\n \"features\": [\n {\n \"type\": \"Feature\",\n \"properties\": {},\n \"geometry\": {\n \"type\": \"Polygon\",\n \"coordinates\": [\n [\n [\n -75.311279296875,\n 41.9921602333763\n ],\n [\n -79.78271484375,\n 42.02481360781777\n ],\n [\n -81.97998046875,\n 41.50857729743935\n ],\n [\n -83.045654296875,\n 38.7283759182398\n ],\n [\n -85.078125,\n 36.641977814705946\n ],\n [\n -86.50634765625,\n 34.994003757575776\n ],\n [\n -88.450927734375,\n 34.397844946449865\n ],\n [\n -88.29711914062499,\n 33.5963189611327\n ],\n [\n -87.4072265625,\n 32.8334428466495\n ],\n [\n -85.49560546875,\n 34.21634468843465\n ],\n [\n -83.3203125,\n 36.59788913307022\n ],\n [\n -81.2109375,\n 37.26530995561875\n ],\n [\n -77.95898437499999,\n 39.7240885773337\n ],\n [\n -75.03662109375,\n 40.54720023441049\n ],\n [\n -75.311279296875,\n 41.9921602333763\n ]\n ]\n ]\n }\n }\n ]\n}","publishingServiceCenter":{"id":9,"text":"Reston PSC"},"noUsgsAuthors":false,"publicationStatus":"PW","scienceBaseUri":"551bb719e4b0323842783a22","contributors":{"authors":[{"text":"Trippi, Michael H. 0000-0002-1398-3427 mtrippi@usgs.gov","orcid":"https://orcid.org/0000-0002-1398-3427","contributorId":941,"corporation":false,"usgs":true,"family":"Trippi","given":"Michael","email":"mtrippi@usgs.gov","middleInitial":"H.","affiliations":[{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true}],"preferred":true,"id":542888,"contributorType":{"id":1,"text":"Authors"},"rank":1},{"text":"Ruppert, Leslie F. 0000-0002-7453-1061 lruppert@usgs.gov","orcid":"https://orcid.org/0000-0002-7453-1061","contributorId":660,"corporation":false,"usgs":true,"family":"Ruppert","given":"Leslie","email":"lruppert@usgs.gov","middleInitial":"F.","affiliations":[{"id":245,"text":"Eastern Mineral and Environmental Resources Science Center","active":true,"usgs":true},{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true}],"preferred":true,"id":542889,"contributorType":{"id":1,"text":"Authors"},"rank":2},{"text":"Attanasi, Emil 0000-0001-6845-7160 attanasi@usgs.gov","orcid":"https://orcid.org/0000-0001-6845-7160","contributorId":1809,"corporation":false,"usgs":true,"family":"Attanasi","given":"Emil","email":"attanasi@usgs.gov","affiliations":[{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true}],"preferred":true,"id":542890,"contributorType":{"id":1,"text":"Authors"},"rank":3},{"text":"Milici, Robert C. rmilici@usgs.gov","contributorId":563,"corporation":false,"usgs":true,"family":"Milici","given":"Robert","email":"rmilici@usgs.gov","middleInitial":"C.","affiliations":[{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true}],"preferred":true,"id":542891,"contributorType":{"id":1,"text":"Authors"},"rank":4},{"text":"Freeman, P.A. 0000-0002-0863-7431 pfreeman@usgs.gov","orcid":"https://orcid.org/0000-0002-0863-7431","contributorId":3154,"corporation":false,"usgs":true,"family":"Freeman","given":"P.A.","email":"pfreeman@usgs.gov","affiliations":[{"id":241,"text":"Eastern Energy Resources Science Center","active":true,"usgs":true}],"preferred":false,"id":542892,"contributorType":{"id":1,"text":"Authors"},"rank":5}]}} ,{"id":70055606,"text":"pp1708G.4 - 2014 - Results of coalbed-methane drilling, Meadowfill Landfill, Harrison County, West Virginia","interactions":[{"subject":{"id":70055606,"text":"pp1708G.4 - 2014 - Results of coalbed-methane drilling, Meadowfill Landfill, Harrison County, West Virginia","indexId":"pp1708G.4","publicationYear":"2014","noYear":false,"chapter":"G.4","title":"Results of coalbed-methane drilling, Meadowfill Landfill, Harrison County, West Virginia"},"predicate":"IS_PART_OF","object":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"id":1}],"isPartOf":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"lastModifiedDate":"2020-05-14T18:59:59.565012","indexId":"pp1708G.4","displayToPublicDate":"2015-03-31T09:15:00","publicationYear":"2014","noYear":false,"publicationType":{"id":18,"text":"Report"},"publicationSubtype":{"id":5,"text":"USGS Numbered Series"},"seriesTitle":{"id":331,"text":"Professional Paper","code":"PP","onlineIssn":"2330-7102","printIssn":"1044-9612","active":true,"publicationSubtype":{"id":5}},"seriesNumber":"1708","chapter":"G.4","title":"Results of coalbed-methane drilling, Meadowfill Landfill, Harrison County, West Virginia","docAbstract":"

The U.S. Environmental Protection Agency funded drilling of a borehole (39.33889°N., 80.26542°W.) to evaluate the potential of enhanced coalbed-methane production from unminable Pennsylvanian coal beds at the Meadowfill Landfill near Bridgeport, Harrison County, W. Va. The drilling commenced on June 17, 2004, and was completed on July 1, 2004. The total depth of the borehole was 1,081 feet (ft) and contained 1,053.95 ft of Pennsylvanian coal-bearing strata, and 27.05 ft of Mississippian strata.

\n

A total of 37.02 ft of high-volatile A and B bituminous Pennsylvanian coal was cored and desorbed from the Harlem, Brush Creek, Upper Freeport, Upper Kittanning upper split, and Upper Kittanning coal beds and the Clarion coal zone. Intact coal intervals were desorbed for a maximum period of 92 days before they were crushed to approximately 10-mesh to determine residual gas amounts. Crushed coal was desorbed for a period of 36 days. Measured gas content, on a dry, ash-free basis, ranged from 79.69 standard cubic feet per ton (SCF/ton), or 2.49 cubic centimeters per gram (cc/g), for the Harlem coal bed to 223.21 SCF/ton, or 6.98 cc/g, for the Clarion coal zone.

\n

Methane contents of desorbed gas from coal samples in the Meadowfill Landfill study area ranged from 14.87 to 98.73 percent (corrected for air contamination) for the Harlem coal bed and Clarion coal zone, respectively. Proportions of methane to the sum of the higher molecular weight hydrocarbons ranged from about 40 to 340 as the desorbed gas contained only a small percentage of higher weight hydrocarbons. Coalbed methane from the Upper Kittanning upper split and the Upper Kittanning coal beds is thermogenic in origin with isotopic composition of carbon (carbon 13, 13C) in methane (expressed as δ13C in units of parts per thousand (per mil) relative to the Vienna Peedee belemnite (VPDB) standard) ranging from -46.6 to -48.7 per mil. Coalbed methane from the Brush Creek and Upper Freeport coal beds and the Clarion coal zone contains some biogenic methane with δ13C values ranging from -51.05 to -51.56 per mil.

","largerWorkType":{"id":18,"text":"Report"},"largerWorkTitle":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character (Professional Paper 1708)","largerWorkSubtype":{"id":5,"text":"USGS Numbered Series"},"language":"English","publisher":"U.S. Geological Survey","publisherLocation":"Reston, VA","doi":"10.3133/pp1708G.4","usgsCitation":"Ruppert, L.F., Trippi, M.H., Fedorko, N., Grady, W.C., Eble, C.F., and Schuller, W.A., 2014, Results of coalbed-methane drilling, Meadowfill Landfill, Harrison County, West Virginia: U.S. Geological Survey Professional Paper 1708, Report: v, 22 p.; Appendix A, https://doi.org/10.3133/pp1708G.4.","productDescription":"Report: v, 22 p.; Appendix A","numberOfPages":"29","onlineOnly":"Y","additionalOnlineFiles":"Y","ipdsId":"IP-005764","costCenters":[{"id":241,"text":"Eastern Energy Resources Science 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A.","contributorId":118228,"corporation":false,"usgs":true,"family":"Schuller","given":"William","email":"","middleInitial":"A.","affiliations":[],"preferred":false,"id":542886,"contributorType":{"id":1,"text":"Authors"},"rank":6}]}} ,{"id":70055609,"text":"pp1708G.3 - 2014 - Results of coalbed-methane drilling, Mylan Park, Monongalia County, West Virginia","interactions":[{"subject":{"id":70055609,"text":"pp1708G.3 - 2014 - Results of coalbed-methane drilling, Mylan Park, Monongalia County, West Virginia","indexId":"pp1708G.3","publicationYear":"2014","noYear":false,"chapter":"G.3","title":"Results of coalbed-methane drilling, Mylan Park, Monongalia County, West Virginia"},"predicate":"IS_PART_OF","object":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"id":1}],"isPartOf":{"id":70143874,"text":"pp1708 - 2014 - Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character","indexId":"pp1708","publicationYear":"2014","noYear":false,"title":"Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character"},"lastModifiedDate":"2020-05-14T19:02:54.372212","indexId":"pp1708G.3","displayToPublicDate":"2015-03-27T15:45:00","publicationYear":"2014","noYear":false,"publicationType":{"id":18,"text":"Report"},"publicationSubtype":{"id":5,"text":"USGS Numbered Series"},"seriesTitle":{"id":331,"text":"Professional Paper","code":"PP","onlineIssn":"2330-7102","printIssn":"1044-9612","active":true,"publicationSubtype":{"id":5}},"seriesNumber":"1708","chapter":"G.3","title":"Results of coalbed-methane drilling, Mylan Park, Monongalia County, West Virginia","docAbstract":"

The Department of Energy National Energy Technology 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 Pennsylvanian coal-bearing strata, 739.67 ft of Mississippian strata, and 301.93 ft of Devonian strata.

\n

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.

\n

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.

\n

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 canister 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 methane (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, suggesting that it contains some microbial gas.

\n

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 adsorption isotherms show that the coals from the Upper Kittanning coal bed and the Middle Kittanning coal zone are undersaturated in methane, but coals from the Clarion coal zone are close to saturation.

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Coalbed methane (CBM) occurs in coal beds of Mississippian and Pennsylvanian (Carboniferous) age in the northern, central, and southern Appalachian basin coal regions, which extend almost continuously from Pennsylvania southward to Alabama. Most commercial CBM production in the Appalachian basin is from three structural subbasins: (1) the Dunkard basin in Pennsylvania, Ohio, and northern West Virginia; (2) the Pocahontas basin in southern West Virginia, eastern Kentucky, and southwestern Virginia; and (3) part of the Black Warrior basin in Alabama. The cumulative CBM production in the Dunkard basin through 2005 was 17 billion cubic feet (BCF), the production in the Pocahontas basin through 2006 was 754 BCF, and the production in the part of the Black Warrior basin in Alabama through 2007 was 2.008 TCF.

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CBM development may be regarded as mature in Alabama, where annual production from 1998 through 2007 was relatively constant and ranged from 112 to 121 BCF. An opportunity still exists for additional growth in the Pocahontas basin. In 2005, annual CBM production in the Pocahontas basin in Virginia and West Virginia was 85 BCF. In addition, opportunities are emerging for producing the large, diffuse CBM resources in the Dunkard basin as additional wells are drilled and technology improves.

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The Carboniferous Coal-bed Gas Total Petroleum System, which lies within the central and southern Appalachian basin, consists of the following five assessment units (AUs): (1) the Pocahontas Basin AU in southern West Virginia, eastern Kentucky, and southwestern Virginia; (2) the Central Appalachian Shelf AU in Tennessee, eastern Kentucky, and southern West Virginia; (3) the East Dunkard (Folded) AU in western Pennsylvania and northern West Virginia; (4) the West Dunkard (Unfolded) AU in Ohio and adjacent parts of Pennsylvania and West Virginia; and (5) the Appalachian Anthracite and Semi-Anthracite AU in Pennsylvania and Virginia. Only two of these assessment units were assessed quantitatively by the U.S. Geological Survey (USGS) in the National Oil and Gas Assessment in 2002. The USGS estimated the Pocahontas Basin AU and the East Dunkard (Folded) AU to contain a mean of about 3.6 and 4.8 trillion cubic feet (TCF) of undiscovered, technically recoverable gas, respectively.

\n

In general, the coal beds of the Carboniferous Coal-bed Gas Total Petroleum System (which are both the source rock and the reservoir) were deposited as peat together with their associated sedimentary strata in Mississippian and Pennsylvanian (Carboniferous) time. The generation of biogenic (microbial) gas probably began as soon as the peat deposits formed. Microbial gas generation is probably occurring at present to some degree throughout the Appalachian basin, wherever the coal beds are relatively shallow and wet. As a result of significant depth of burial, compaction, and coalification during the late Paleozoic and early Mesozoic, the coal beds were heated sufficiently to generate thermogenic gas (coalbed methane) in the eastern part of the Appalachian basin.

\n

Trap formation began with the deposition of the peat deposits during the Mississippian and continued into the Late Pennsylvanian and Permian, when strata of the Appalachian Plateaus were deformed during the Alleghanian orogeny. The seals are the connate waters that occupy fractures and larger pore spaces within the coal beds, as well as the fine-grained, siliciclastic sedimentary strata that are intercalated with the coal. The critical moment for the petroleum system occurred during the Alleghanian orogeny, when deformation resulted in the geologic structures in the eastern part of the Appalachian basin that enhanced fracture porosity within the coal beds. In places, burial by thrust sheets (thrust loading) in the Valley and Ridge physiographic province may have resulted in the additional generation of thermogenic coalbed methane in the Pennsylvania Anthracite region and in the semianthracite deposits of Virginia and West Virginia, although other explanations have been offered.

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This chapter is a re-release of U.S. Geological Survey Scientific Investigations Map 2985, of the same title, by Ryder and others (2008). For this chapter, two appendixes have been added that do not appear with the original version. Appendix A provides Log ASCII Standard (LAS) files for each drill hole along cross-section E–E'; they are text files which encode gamma-ray, neutron, density, and other logs that can be used by most well-logging software. Appendix B provides graphic well-log traces from each drill hole.

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Thermal maturation patterns of Pennsylvanian strata in the Appalachian basin and part of the Black Warrior basin were determined by compiling previously published and unpublished percent-vitrinite-reflectance (%R0) measurements and preparing isograd maps on the basis of the measurements. The isograd values range from 0.6 %R0 in Ohio and the western side of the Eastern Kentucky coal field to 5.5 %R0 in the Southern field in the Pennsylvania Anthracite region, Schuylkill County, Pa. The vitrinite-reflectance values correspond to the American Society of Testing Materials (ASTM) coal-rank classes of high-volatile C bituminous to meta-anthracite, respectively. In general, the isograds show that thermal maturity patterns of Pennsylvanian coals within the Appalachian basin generally decrease from east to west. In the Black Warrior basin of Alabama, the isograds show a circular pattern with the highest values (greater than 1.6 %R0) centered in Jefferson County, Ala. Most of the observed patterns can be explained by variations in the depth of burial, variations in geothermal gradient, or a combination of both; however, there are at least four areas of higher ranking coal in the Appalachian basin that are difficult to explain by these two processes alone: (1) a set of west- to northwest-trending salients centered in Somerset, Cambria, and Fayette Counties, Pa.; (2) an elliptically shaped, northeast-trending area centered in southern West Virginia and western Virginia; (3) the Pennsylvania Anthracite region in eastern Pennsylvania; and (4) the eastern part of the Black Warrior coal field in Alabama. The areas of high-ranking coal in southwestern Pennsylvania, the Black Warrior coal field, and the Pennsylvania Anthracite region are interpreted here to represent areas of higher paleo-heat flow related to syntectonic movement of hot fluids towards the foreland associated with Alleghanian deformation. In addition to the higher heat flow from these fluids, the Pennsylvania Anthracite region also was buried more deeply than other parts of the Appalachian basin. The area of high rank coal in southwestern Virginia probably was controlled primarily by overburden thickness, but may also have been influenced by higher geothermal gradients.
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