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Sample records for appalachian basin exploration

  1. CREATING A GEOLOGIC PLAY BOOK FOR TRENTON-BLACK RIVER APPALACHIAN BASIN EXPLORATION

    SciTech Connect

    Douglas G. Patchen; James Drahovzal; Larry Wickstrom; Taury Smith; Chris Laughery; Katharine Lee Avary

    2004-04-01

    Private- and public-sector stakeholders formed the new ''Trenton-Black River Appalachian Basin Exploration Consortium'' and began a two-year research effort that will lead to a play book for Trenton-Black River exploration throughout the Appalachian basin. The final membership of the Consortium includes 17 gas exploration companies and 6 research team members, including the state geological surveys in Kentucky, Ohio, Pennsylvania and West Virginia, the New York State Museum Institute and West Virginia University. Seven integrated research tasks are being conducted by basin-wide research teams organized from this large pool of experienced professionals. More than 3400 miles of Appalachian basin digital seismic data have been quality checked. In addition, inquiries have been made regarding the availability of additional seismic data from government and industry partners in the consortium. Interpretations of the seismic data have begun. Error checking is being performed by mapping the time to various prominent reflecting horizons, and analyzing for any anomalies. A regional geological velocity model is being created to make time-to-depth conversions. Members of the stratigraphy task team compiled a generalized, basin-wide correlation chart, began the process of scanning geophysical logs and laid out lines for 16 regional cross sections. Two preliminary cross sections were constructed, a database of all available Trenton-Black River cores was created, and a basin-wide map showing these core locations was produced. Two cores were examined, described and photographed in detail, and were correlated to the network of geophysical logs. Members of the petrology team began the process of determining the original distribution of porous and permeable facies within a sequence stratigraphic framework. A detailed sedimentologic and petrographic study of the Union Furnace road cut in central Pennsylvania was completed. This effort will facilitate the calibration of subsurface core

  2. Appalachian basin bibliography. Topical report, March 1994

    SciTech Connect

    Picciano, L.; Armstrong, T.S.

    1994-03-01

    More than 120 Gas Research Institute reports on gas exploration and production in the Appalachian Basin are listed. They cover geology and reservoir engineering in three gas producing formations: shales, tight gas sands, and coal seams.

  3. CREATING A GEOLOGIC PLAY BOOK FOR TRENTON-BLACK RIVER APPALACHIAN BASIN EXPLORATION

    SciTech Connect

    Douglas G. Patchen; Katharine Lee Avary; John M. Bocan; Michael Hohn; John B. Hickman; Paul D. Lake; James A. Drahovzal; Christopher D. Laughrey; Jaime Kostelnik; Taury Smith; Ron Riley; Mark Baranoski

    2005-04-01

    The Trenton-Black River Appalachian Basin Research Consortium has made significant progress toward their goal of producing a geologic play book for the Trenton-Black River gas play. The final product will include a resource assessment model of Trenton-Black River reservoirs; possible fairways within which to concentrate further studies and seismic programs; and a model for the origin of Trenton-Black River hydrothermal dolomite reservoirs. All seismic data available to the consortium have been examined. Synthetic seismograms constructed for specific wells have enabled researchers to correlate the tops of 15 stratigraphic units determined from well logs to seismic profiles in New York, Pennsylvania, Ohio, West Virginia and Kentucky. In addition, three surfaces for the area have been depth converted, gridded and mapped. A 16-layer velocity model has been developed to help constrain time-to-depth conversions. Considerable progress was made in fault trend delineation and seismic-stratigraphic correlation within the project area. Isopach maps and a network of gamma-ray cross sections supplemented with core descriptions allowed researchers to more clearly define the architecture of the basin during Middle and Late Ordovician time, the control of basin architecture on carbonate and shale deposition and eventually, the location of reservoirs in Trenton Limestone and Black River Group carbonates. The basin architecture itself may be structurally controlled, and this fault-related structural control along platform margins influenced the formation of hydrothermal dolomite reservoirs in original limestone facies deposited in high energy environments. This resulted in productive trends along the northwest margin of the Trenton platform in Ohio. The continuation of this platform margin into New York should provide further areas with good exploration potential. The focus of the petrographic study shifted from cataloging a broad spectrum of carbonate rocks that occur in the

  4. CREATING A GEOLOGIC PLAY BOOK FOR TRENTON-BLACK RIVER APPALACHIAN BASIN EXPLORATION

    SciTech Connect

    Douglas G. Patchen; Chris Laughrey; Jaime Kostelnik; James Drahovzal; John B. Hickman; Paul D. Lake; John Bocan; Larry Wickstrom; Taury Smith; Katharine Lee Avary

    2004-10-01

    The ''Trenton-Black River Appalachian Basin Exploration Consortium'' has reached the mid-point in a two-year research effort to produce a play book for Trenton-Black River exploration. The final membership of the Consortium includes 17 exploration and production companies and 6 research team members, including four state geological surveys, the New York State Museum Institute and West Virginia University. Seven integrated research tasks and one administrative and technology transfer task are being conducted basin-wide by research teams organized from this large pool of experienced professionals. All seismic data available to the consortium have been examined at least once. Synthetic seismograms constructed for specific wells have enabled researchers to correlate the tops of 10 stratigraphic units determined from well logs to seismic profiles in New York and Pennsylvania. In addition, three surfaces in that area have been depth converted, gridded and mapped. In the Kentucky-Ohio-West Virginia portion of the study area, a velocity model has been developed to help constrain time-to-depth conversions. Fifteen formation tops have been identified on seismic in that area. Preliminary conclusions based on the available seismic data do not support the extension of the Rome Trough into New York state. Members of the stratigraphy task team measured, described and photographed numerous cores from throughout the basin, and tied these data back to their network of geophysical log cross sections. Geophysical logs were scanned in raster files for use in detailed well examination and construction of cross sections. Logs on these cross sections that are only in raster format are being converted to vector format for final cross section displays. The petrology team measured and sampled one classic outcrop in Pennsylvania and ten cores in four states. More than 600 thin sections were prepared from samples in those four states. A seven-step procedure is being used to analyze all thin

  5. Creating a Geologic Play Book for Trenton-Black River Appalachian Basin Exploration

    SciTech Connect

    Douglas G. Patchen; Taury Smith; Ron Riley; Mark Baranoski; David Harris; John Hickman; John Bocan; Michael Hohn

    2005-09-30

    Preliminary isopach and facies maps, combined with a literature review, were used to develop a sequence of basin geometry, architecture and facies development during Cambrian and Ordovician time. The main architectural features--basins, sub basins and platforms--were identified and mapped as their positions shifted with time. This is significant because a better understanding of the control of basin geometry and architecture on the distribution of key facies and on subsequent reservoir development in Ordovician carbonates within the Trenton and Black River is essential for future exploration planning. Good exploration potential is thought to exist along the entire platform margin, where clean grainstones were deposited in skeletal shoals from Indiana thorough Ohio and Ontario into Pennsylvania. The best reservoir facies for the development of hydrothermal dolomites appears to be these clean carbonates. This conclusion is supported by observations taken in existing fields in Indiana, Ontario, Ohio and New York. In contrast, Trenton-Black River production in Kentucky and West Virginia has been from fractured, but non-dolomitized, limestone reservoirs. Facies maps indicate that these limestones were deposited under conditions that led to a higher argillaceous content than the cleaner limestones deposited in higher-energy environments along platform margins. However, even in the broad area of argillaceous limestones, clean limestone buildups have been observed in eastern outcrops and, if present and dolomitized in the subsurface, may provide additional exploration targets. Structure and isopach maps developed as part of the structural and seismic study supported the basin architecture and geometry conclusions, and from them some structural control on the location of architectural features may be inferred. This portion of the study eventually will lead to a determination of the timing relative to fracturing, dolomitization and hydrocarbon charging of reservoirs in the

  6. Trapping models for the Lower Silurian Medina Sandstone Group - A comparison of trapping styles and exploration methodology for both deep and shallow medina plays in the Appalachian basin

    SciTech Connect

    Zagorski, W.A. )

    1991-08-01

    The Lower Silurian Medina Sandstone Group has been a major oil and gas producer in the Appalachian basin since the late 1800s and remains a primary objective in parts of New York, Ohio, and Pennsylvania. Although classified as a stratigraphic trap, production from the Medina is obtained from a wide variety of trapping conditions ranging from pure stratigraphic to structural stratigraphic in the shallower producing areas of the Medina to deep basin (i.e., Elmworth field, western Canada) trapping in the deeper producing regions of strategies must be employed for optimum prospect development and maximum economic success ratios. Several producing areas of the Medina are presented to compare and contrast these various trapping mechanisms together with suggested exploration models applicable to each trap type.

  7. Atlas of major Appalachian basin gas plays

    SciTech Connect

    Aminian, K.; Avary, K.L.; Baranoski, M.T.; Flaherty, K.; Humphreys, M.; Smosna, R.A.

    1995-06-01

    This regional study of gas reservoirs in the Appalachian basin has four main objectives: to organize all of the -as reservoirs in the Appalachian basin into unique plays based on common age, lithology, trap type and other geologic similarities; to write, illustrate and publish an atlas of major gas plays; to prepare and submit a digital data base of geologic, engineering and reservoir parameters for each gas field; and technology transfer to the oil and gas industry during the preparation of the atlas and data base.

  8. Iron control in the Appalachian Basin

    SciTech Connect

    Dill, W.R.; Fredette, G.

    1983-11-01

    The Appalachian Basin presents one of the most challenging production and stimulation problems because of the iron content of its hydrocarbon producing formations. A variety of iron compounds in the producing formations present problems that have to be considered to effectively stimulate these formations. A research program was initiated in the later part of 1980 to determine methods of more effectively controlling the iron problems in the Appalachian Basin. Results of this study provide data for comparing the effectiveness of various iron control systems that are used in acid stimulation or breakdown techniques that minimize the release of acid insoluble solids and stabilizes them to decrease the detrimental effect caused by fines migration. Also developed in this study was an iron control system that helps the compatibility of the treating fluid with ferrous iron in the formation water. Flow test data and field results indicate the effectiveness of these iron control systems and treating techniques.

  9. Selecting major Appalachian basin gas plays

    SciTech Connect

    Patchen, D.G.; Nuttall, B.C.; Baranoski, M.T.; Harper, J.A.; Schwietering, J.F.; Van Tyne, A.; Aminian, K.; Smosna, R.A.

    1992-01-01

    Under a cooperative agreement with the Morgantown Energy Technology Center (METC) the Appalachian Oil and Natural Gas Research Consortium (AONGRC) is preparing a geologic atlas of the major gas plays in the Appalachian basin, and compiling a database for all fields in each geologic play. the first obligation under this agreement was to prepare a topical report that identifies the major gas plays, briefly describes each play, and explains how the plays were selected. Four main objectives have been defined for this initial task: assign each gas reservoir to a geologic play, based on age, trap type, degree of structural control, and depositional environment; organize all plays into geologically-similar groups based on the main criteria that defines each play; prepare a topical report for METC; and transfer this technology to industry through posters and talks at regional geological and engineering meetings including the Appalachian Petroleum Geology Symposium, Northeastern Section meeting of the Geological Society of America, the METC Gas Contractors Review meeting, the Kentucky Oil and Gas Association, and the Appalachian Energy Group.

  10. Selecting major Appalachian basin gas plays

    SciTech Connect

    Patchen, D.G.; Nuttall, B.C.; Baranoski, M.T.; Harper, J.A.; Schwietering, J.F.; Van Tyne, A.; Aminian, K.; Smosna, R.A.

    1992-06-01

    Under a cooperative agreement with the Morgantown Energy Technology Center (METC) the Appalachian Oil and Natural Gas Research Consortium (AONGRC) is preparing a geologic atlas of the major gas plays in the Appalachian basin, and compiling a database for all fields in each geologic play. the first obligation under this agreement was to prepare a topical report that identifies the major gas plays, briefly describes each play, and explains how the plays were selected. Four main objectives have been defined for this initial task: assign each gas reservoir to a geologic play, based on age, trap type, degree of structural control, and depositional environment; organize all plays into geologically-similar groups based on the main criteria that defines each play; prepare a topical report for METC; and transfer this technology to industry through posters and talks at regional geological and engineering meetings including the Appalachian Petroleum Geology Symposium, Northeastern Section meeting of the Geological Society of America, the METC Gas Contractors Review meeting, the Kentucky Oil and Gas Association, and the Appalachian Energy Group.

  11. Early history of the Michigan basin: Subsidence and Appalachian tectonics

    SciTech Connect

    Howell, P.D.; van der Pluijm, B.A. )

    1990-12-01

    Geometries of Cambrian to Silurian stratigraphic sequences in the Michigan basin record discrete episodes of basin-centered subsidence separated by periods of regional tilting. Backstripping reveals irregular subsidence rates that argue against a simple thermal contraction model. Depositional facies architecture also reflects episodic subsidence patterns, basin-centered facies tracts dominating during subsidence reactivations. These three lines of evidence indicate that subsidence cessations and reactivations characterize the early history of the Michigan basin. Periods of episodic subsidence correlate temporally with orogenic events in the Appalachians, suggesting that reactivation of basin subsidence is related to tectonic activity. The authors propose that Appalachian orogenic activity caused the episodic subsidence of the Michigan basin, possibly through weakening of the lower crust and reactivation of a preexisting upper-crustal isotatic imbalance.

  12. Early history of the Michigan basin: Subsidence and Appalachian tectonics

    NASA Astrophysics Data System (ADS)

    Howell, Paul D.; van der Pluijm, Ben A.

    1990-12-01

    Geometries of Cambrian to Silurian stratigraphc sequences in the Michigan basin record discrete episodes of basin-centered subsidence separated by periods of regional tilting. Backstripping reveals irregular subsidence rates that argue against a simple thermal contraction model. Depositional facies architecture also reflects episodic subsidence patterns, basin-centered facies tracts dominating during subsidence reactivations. These three lines of evidence indicate that subsidence cessations and reactivations characterize the early history of the Michigan basin. Periods of episodic subsidence correlate temporally with orogenic events in the Appalachians, suggesting that reactivation of basin subsidence is related to tectonic activity. We propose that Appalachian orogenic activity caused the episodic subsidence of the Michigan basin, possibly through weakening of the lower crust and reactivation of a preexisting upper-crustal isostatic imbalance.

  13. Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    Professional Paper 1708 is intended primarily for geoscientists in academia, industry, and government who are interested in Appalachian basin geology and its coal and petroleum resources. Other users, however, may find the topics, papers, and digital images valuable for land-use and policy planning. Among the anticipated benefits of the report are improvements in (1) resource assessment estimates and methodology, (2) exploration strategies, (3) basin models, and (4) energy use policies.

  14. Pennsylvanian gastropod Pseudozygopleura (Pseudozygopleura) from the Appalachian basin: II

    SciTech Connect

    Hoare, R.E.; Sturgeon, M.T.

    1985-01-01

    Twenty-five additional taxa to those described by Hoare and Sturgeon (1981) of the gastropod Pseudozygopleura (Pseudozygopleura) are described from the Pennsylvania System of the Appalachian Basin. A key for identification of known Pennsylvanian species from this region is included.

  15. Appalachian basin coal-bed methane: Elephant or flea

    SciTech Connect

    Hunt, A.M. )

    1991-08-01

    Historically, interest in the Appalachian basin coal-bed methane resource extends at least over the last 50 years. The Northern and Central Appalachian basins are estimated to contain 61 tcf and 5 tcf of coal-bed methane gas, respectively. Development of this resource has not kept pace with that of other basins, such as the Black Warrior basin of Alabama of the San Juan basin of northern New Mexico and Colorado. Without the benefit of modern completion, stimulation, and production technology, some older Appalachian basin coal-bed methane wells were reported to have produced in excess of 150 used here to characterize some past projects and their results. This work is not intended to comprise a comprehensive survey of all Appalachian basin projects, but rather to provide background information from which to proceed for those who may be interested in doing so. Several constraints to the development of this resource have been identified, including conflicting legal rights of ownership of the gas produced from the coal seams when coal and conventional oil and gas rights are controlled by separate parties. In addition, large leaseholds have been difficult to acquire and finding costs have been high. However, the threshold of minimum economic production may be relatively low when compared with other areas, because low-pressures pipelines are available and gas prices are among the highest in the nation. Interest in the commercial development of the resource seems to be on the increase with several projects currently active and more reported to be planned for the near future.

  16. Effects of Hydrocarbon Extraction on Landscapes of the Appalachian Basin

    USGS Publications Warehouse

    Slonecker, Terry E.; Milheim, Lesley E.; Roig-Silva, Coral M.; Kalaly, Siddiq S.

    2015-09-30

    The need for energy resources has created numerous economic opportunities for hydrocarbon extraction in the Appalachian basin. The development of alternative energy natural gas resources from deep-shale drilling techniques, along with conventional natural gas extraction methods, has created a flurry of wells, roads, pipelines, and related infrastructure across many parts of the region. An unintended and sometimes overlooked consequence of these activities is their effect on the structure and function of the landscape and ecosystems. The collective effect of over 100,000 hydrocarbon extraction permits for oil, coal bed methane, Marcellus and Utica Shale natural gas wells, and other types of hydrocarbon gases and their associated infrastructure has saturated much of the landscape and disturbed the natural environment in the Appalachian basin. The disturbance created by the sheer magnitude of the development of these collective wells and infrastructure directly affects how the landscape and ecosystems function and how they provide ecological goods and services. 

  17. The central and northern Appalachian Basin-a frontier region for coalbed methane development

    USGS Publications Warehouse

    Lyons, P.C.

    1998-01-01

    The Appalachian basin is the world's second largest coalbed-methane (CBM) producing basin. It has nearly 4000 wells with 1996 annual production at 147.8 billion cubic feet (Bcf). Cumulative CBM production is close to 0.9 trillion cubic feet (Tcf). The Black Warrior Basin of Alabama in the southern Appalachian basin (including a very minor amount from the Cahaba coal field) accounts for about 75% of this annual production and about 75% of the wells, and the remainder comes from the central and northern Appalachian basin. The Southwest Virginia coal field accounts for about 95% of the production from the central and northern parts of the Appalachian basin. Production data and trends imply that several of the Appalachian basin states, except for Alabama and Virginia, are in their infancy with respect to CBM development. Total in-place CBM resources in the central and northern Appalachian basin have been variously estimated at 66 to 76 trillion cubic feet (Tcf), of which an estimated 14.55 Tcf (~ 20%) is technically recoverable according to a 1995 U.S. Geological Survey assessment. For comparison in the Black Warrior basin of the 20 Tcf in-place CBM resources, 2.30 Tcf (~ 12%) is technically recoverable. Because close to 0.9 Tcf of CBM has already been produced from the Black Warrior basin and the proved reserves are about 0.8 Tcf for 1996 [Energy Information Administration (EIA), 1997]. U.S. Crude Oil, Natural Gas, and Natural Gas Liquids Reserves, 1996 Annual Report. U.S. Department of Energy DOE/EIA-0216(96), 145 pp.], these data imply that the central and northern Appalachian basin could become increasingly important in the Appalachian basin CBM picture as CBM resources are depleted in the southern Appalachian basin (Black Warrior Basin and Cahaba Coal Field). CBM development in the Appalachian states could decrease the eastern U.S.A.'s dependence on coal for electricity. CBM is expected to provide over the next few decades a virtually untapped source of

  18. Assessment of undiscovered carboniferous coal-bed gas resources of the Appalachian Basin and Black Warrior Basin Provinces, 2002

    SciTech Connect

    Milici, R.C.; Hatch, J.R.

    2004-09-15

    Coalbed methane (CBM) occurs in coal beds of Mississippian and Pennsylvanian (Carboniferous) age in the Appalachian basin, which extends almost continuously from New York to Alabama. In general, the basin includes three structural subbasins: the Dunkard basin in Pennsylvania, Ohio, and northern West Virginia; the Pocahontas basin in southern West Virginia, eastern Kentucky, and southwestern Virginia; and the Black Warrior basin in Alabama and Mississippi. For assessment purposes, the Appalachian basin was divided into two assessment provinces: the Appalachian Basin Province from New York to Alabama, and the Black Warrior Basin Province in Alabama and Mississippi. By far, most of the coalbed methane produced in the entire Appalachian basin has come from the Black Warrior Basin Province. 8 refs., 1 fig., 1 tab.

  19. Appalachian coal assessment: Defining the coal systems of the Appalachian basin

    USGS Publications Warehouse

    Milici, R.C.

    2005-01-01

    The coal systems concept may be used to organize the geologic data for a relatively large, complex area, such as the Appalachian basin, in order to facilitate coal assessments in the area. The concept is especially valuable in subjective assessments of future coal production, which would require a detailed understanding of the coal geology and coal chemistry of the region. In addition, subjective assessments of future coal production would be enhanced by a geographical information system that contains the geologic and geochemical data commonly prepared for conventional coal assessments. Coal systems are generally defined as one or more coal beds or groups of coal beds that have had the same or similar genetic history from their inception as peat deposits, through their burial, diagenesis, and epigenesis to their ultimate preservation as lignite, bituminous coal, or anthracite. The central and northern parts of the Appalachian basin contain seven coal systems (Coal Systems A-G). These systems may be defined generally on the following criteria: (1) on the primary characteristics of their paleopeat deposits, (2) on the stratigraphic framework of the Paleozoic coal measures, (3) on the relative abundance of coal beds within the major stratigraphic groupings, (4) on the amount of sulfur related to the geologic and climatic conditions under which paleopeat deposits accumulated, and (5) on the rank of the coal (lignite to anthracite). ??2005 Geological Society of America.

  20. Microfabric analysis of the Appalachian basin Williamson and Willowvale shales

    SciTech Connect

    Burkins, D.L.; Woodard, M. . Geology Dept.)

    1993-03-01

    Shale samples from the Williamson and Willovale formations (Upper Llandoverian, Silurian) were studied to determine the relationship of microfabric (particle orientation) to sedimentary environment and processes. The shales were sampled along a traverse from Utica to Rochester, New York in the Appalachian foreland basin. Samples were taken from proximal and distal parts of the basin and analyzed using a scanning electron microscope (SEM) and using thin sections to determine the relationship between microfabric and basin position. Results show samples taken from the proximal part of the basin contain large amounts of silt grains, random orientation of clay flakes, and a high degree of bioturbation. Basinward, the samples become less silty, less bioturbated, and have more preferred orientation of clay flakes. The samples at the basin axis show the highest degree of preferred orientation and contain no silt grains. It can be concluded that the shale fabrics vary basinward and microfabric analysis is useful in determining the relative position of samples within a sedimentary basin.

  1. Geology of the Devonian black shales of the Appalachian basin

    USGS Publications Warehouse

    Roen, J.B.

    1983-01-01

    Black shales of Devonian age in the Appalachian basin are a unique rock sequence. The high content of organic matter, which imparts the characteristic lithology, has for years attracted considerable interest in the shales as a possible source of energy. Concurrent with periodic and varied economic exploitations of the black shales are geologic studies. The recent energy shortage prompted the U.S. Department of Energy through the Eastern Gas Shales Project of the Morgantown Energy Technology Center to underwrite a research program to determine the geologic, geochemical, and structural characteristics of the Devonian black shales in order to enhance the recovery of gas from the shales. Geologic studies produced a regional stratigraphic network that correlates the 15-foot sequence in Tennessee with 3,000 feet of interbedded black and gray shales in central New York. The classic Devonian black-shale sequence in New York has been correlated with the Ohio Shale of Ohio and Kentucky and the Chattanooga Shale of Tennessee and southwestern Virginia. Biostratigraphic and lithostratigraphic markers in conjunction with gamma-ray logs facilitated long range correlations within the Appalachian basin and provided a basis for correlations with the black shales of the Illinois and Michigan basins. Areal distribution of selected shale units along with paleocurrent studies, clay mineralogy, and geochemistry suggests variations in the sediment source and transport directions. Current structures, faunal evidence, lithologic variations, and geochemical studies provide evidence to support interpretation of depositional environments. In addition, organic geochemical data combined with stratigraphic and structural characteristics of the shale within the basin allow an evaluation of the resource potential of natural gas in the Devonian shale sequence.

  2. Geology of the Devonian black shales of the Appalachian Basin

    USGS Publications Warehouse

    Roen, J.B.

    1984-01-01

    Black shales of Devonian age in the Appalachian Basin are a unique rock sequence. The high content of organic matter, which imparts the characteristic lithology, has for years attracted considerable interest in the shales as a possible source of energy. The recent energy shortage prompted the U.S. Department of Energy through the Eastern Gas Shales Project of the Morgantown Energy Technology Center to underwrite a research program to determine the geologic, geochemical, and structural characteristics of the Devonian black shales in order to enhance the recovery of gas from the shales. Geologic studies by Federal and State agencies and academic institutions produced a regional stratigraphic network that correlates the 15 ft black shale sequence in Tennessee with 3000 ft of interbedded black and gray shales in central New York. These studies correlate the classic Devonian black shale sequence in New York with the Ohio Shale of Ohio and Kentucky and the Chattanooga Shale of Tennessee and southwestern Virginia. Biostratigraphic and lithostratigraphic markers in conjunction with gamma-ray logs facilitated long-range correlations within the Appalachian Basin. Basinwide correlations, including the subsurface rocks, provided a basis for determining the areal distribution and thickness of the important black shale units. The organic carbon content of the dark shales generally increases from east to west across the basin and is sufficient to qualify as a hydrocarbon source rock. Significant structural features that involve the black shale and their hydrocarbon potential are the Rome trough, Kentucky River and Irvine-Paint Creek fault zone, and regional decollements and ramp zones. ?? 1984.

  3. Coalbed methane resources of the Appalachian Basin, eastern USA

    USGS Publications Warehouse

    Milici, Robert C.; Hatch, Joseph R.; Pawlewicz, Mark J.

    2010-01-01

    In 2002, the U.S. Geological Survey (USGS) assessed the technically recoverable, undiscovered coalbed-gas resources in the Appalachian basin and Black Warrior basin Assessment Provinces as about 15.5 trillion cubic feet. Although these resources are almost equally divided between the two areas, most of the production occurs within relatively small areas within these Provinces, where local geological and geochemical attributes have resulted in the generation and retention of large amounts of methane within the coal beds and have enhanced the producibility of the gas from the coal. In the Appalachian basin, coalbed methane (CBM) tests are commonly commercial where the cumulative coal thickness completed in wells is greater than three meters (10 ft), the depth of burial of the coal beds is greater than 100 m (350 ft), and the coal is in the thermogenic gas window. In addition to the ubiquitous cleating within the coal beds, commercial production may be enhanced by secondary fracture porosity related to supplemental fracture systems within the coal beds. In order to release the methane from microporus coal matrix, most wells are dewatered prior to commercial production of gas. Two Total Petroleum Systems (TPS) were defined by the USGS during the assessment: the Pottsville Coal-bed gas TPS in Alabama, and the Carboniferous Coal-bed Gas TPS in Pennsylvania, Ohio, West Virginia, eastern Kentucky, Virginia, Tennessee, and Alabama. These were divided into seven assessment units, of which three had sufficient data to be assessed. Production rates are higher in most horizontal wells drilled into relatively thick coal beds, than in vertical wells; recovery per unit area is greater, and potential adverse environmental impact is decreased.

  4. Executive summary: Chapter A.1 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ruppert, Leslie F.; Ryder, Robert T.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    This publication supplements and updates older USGS regional studies of Appalachian basin coal and petroleum resources such as those by Arndt and others (1968) and the numerous contributors to USGS Miscellaneous Map Series I−917 (for example, Harris and others, 1978), respectively. USGS Professional Paper 1708 is intended primarily for geoscientists in academia, industry, and government who are interested in Appalachian basin geology and its coal and petroleum resources. Other users, however, may find the wide variety of topics, papers, and digital images of value for landuse and policy planning issues. Among the anticipated benefits of the report are improvements in (1) resource assessment estimates and methodology, (2) exploration strategies, (3) basin models, and

  5. Executive summary: Chapter A.1 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ruppert, Leslie F.; Ryder, Robert T.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    This publication supplements and updates older USGS regional studies of Appalachian basin coal and petroleum resources such as those by Arndt and others (1968) and the numerous contributors to USGS Miscellaneous Map Series I−917 (for example, Harris and others, 1978), respectively. USGS Professional Paper 1708 is intended primarily for geoscientists in academia, industry, and government who are interested in Appalachian basin geology and its coal and petroleum resources. Other users, however, may find the wide variety of topics, papers, and digital images of value for landuse and policy planning issues. Among the anticipated benefits of the report are improvements in (1) resource assessment estimates and methodology, (2) exploration strategies, (3) basin models, and (4) energy use policies.

  6. Overview of the potential and identified petroleum source rocks of the Appalachian basin, eastern United States: Chapter G.13 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Coleman, James L.; Ryder, Robert T.; Milici, Robert C.; Brown, Stephen; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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.

  7. Coalbed-methane production in the Appalachian basin: Chapter G.2 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Milici, Robert C.; Polyak, Désirée E.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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. 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.

  8. Paleozoic unconformities favorable for uranium concentration in northern Appalachian basin

    SciTech Connect

    Dennison, J.M.

    1986-05-01

    Unconformities can redistribute uranium from protore rock as ground water moves through poorly consolidated strata beneath the erosion surface, or later moves along the unconformity. Groundwater could migrate farther than in present-day lithified Paleozoic strata in the Appalachian basin, now locally deformed by the Taconic and Allegheny orogenies. Several paleoaquifer systems could have developed uranium geochemical cells. Sandstone mineralogy, occurrences of fluvial strata, and reduzate facies are important factors. Other possibilities include silcrete developed during desert exposure, and uranium concentrated in paleokarst. Thirteen unconformities are evaluated to determine favorable areas for uranium concentration. Cambrian Potsdam sandstone (New York) contains arkoses and possible silcretes just above crystalline basement. Unconformities involving beveled sandstones and possible fluvial strata include Cambrian Hardyston sandstone (New Jersey), Cambrian Potsdam Sandstone (New York), Ordovician Oswego and Juniata formations (Pennsylvania and New York), Silurian Medina Group (New York), and Silurian Vernon, High Falls, and Longwood formations (New York and New Jersey). Devonian Catskill Formation is beveled by Pennsylvanian strata (New York and Pennsylvania). The pre-Pennsylvanian unconformity also bevels Lower Mississippian Pocono, Knapp, and Waverly strata (Pennsylvania, New York, and Ohio), truncates Upper Mississippian Mauch Chunk Formation (Pennsylvania), and forms paleokarst on Mississippian Loyalhanna Limestone (Pennsylvania) and Maxville Limestone (Ohio). Strata associated with these unconformities contain several reports of uranium. Unconformities unfavorable for uranium concentration occur beneath the Middle Ordovician (New York), Middle Devonian (Ohio and New York), and Upper Devonian (Ohio and New York); these involve marine strata overlying marine strata and probably much submarine erosion.

  9. Appalachian Basin Low-Permeability Sandstone Reservoir Characterizations

    SciTech Connect

    Ray Boswell; Susan Pool; Skip Pratt; David Matchen

    1993-04-30

    A preliminary assessment of Appalachian basin natural gas reservoirs designated as 'tight sands' by the Federal Energy Regulatory Commission (FERC) suggests that greater than 90% of the 'tight sand' resource occurs within two groups of genetically-related units; (1) the Lower Silurian Medina interval, and (2) the Upper Devonian-Lower Mississippian Acadian clastic wedge. These intervals were targeted for detailed study with the goal of producing geologic reservoir characterization data sets compatible with the Tight Gas Analysis System (TGAS: ICF Resources, Inc.) reservoir simulator. The first phase of the study, completed in September, 1991, addressed the Medina reservoirs. The second phase, concerned with the Acadian clastic wedge, was completed in October, 1992. This report is a combined and updated version of the reports submitted in association with those efforts. The Medina interval consists of numerous interfingering fluvial/deltaic sandstones that produce oil and natural gas along an arcuate belt that stretches from eastern Kentucky to western New York. Geophysical well logs from 433 wells were examined in order to determine the geologic characteristics of six separate reservoir-bearing intervals. The Acadian clastic wedge is a thick, highly-lenticular package of interfingering fluvial-deltaic sandstones, siltstones, and shales. Geologic analyses of more than 800 wells resulted in a geologic/engineering characterization of seven separate stratigraphic intervals. For both study areas, well log and other data were analyzed to determine regional reservoir distribution, reservoir thickness, lithology, porosity, water saturation, pressure and temperature. These data were mapped, evaluated, and compiled into various TGAS data sets that reflect estimates of original gas-in-place, remaining reserves, and 'tight' reserves. The maps and data produced represent the first basin-wide geologic characterization for either interval. This report outlines the methods and

  10. Coal and coalbed-methane resources in the Appalachian and Black Warrior basins: maps showing the distribution of coal fields, coal beds, and coalbed-methane fields: Chapter D.1 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Trippi, Michael H.; Ruppert, Leslie F.; Milici, Robert C.; Kinney, Scott A.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    The study area for most reports in this volume is the Appalachian basin. The term “Appalachian basin study area” (shortened from “Appalachian basin geologic framework study area”) includes all of the Appalachian Basin Province (Province 67) and part of the neighboring Black Warrior Basin Province (Province 65) of Dolton and others (1995). The boundaries for these two provinces and the study area are shown on figure 1.

  11. Liquid propellant stimulation of shallow Appalachian Basin wells

    SciTech Connect

    Watson, S.C.; Benson, G.R.

    1984-09-01

    Stimulation trials have been conducted on more than thirty oil and/or gas wells in the Appalachian Basin by the Otto Torpedo Co. with a new liquid propellant developed by Hercules Incorporated called RE-FLO 403. A dense pourable oil unaffected by water of hydrostatic pressures up to 400 Psi, RE-FLO 403 liquid propellant differs from high explosives in that it is not cap-sensitive and exhibits a detonation velocity and shock wave energy like a solid propellant. However, it differs from solid propellants in that it does not require center priming or water-tight containers and generates a high gaseous expansion energy per unit volume like an explosive. As applied in conventional soft-metal torpedo well shooting by the Otto Torpedo Co. coupled with either a liquid or gravel confinement, RE-FLO 403 gave short post-treatment clean-out times. In most cases, pumping was resumed within 1-2 days. Twenty-five of the first thirty wells stimulated with RE-FLO 403 showed fair to excellent improvement in yield. At the end of 30 days production the combined output of eleven new wells was 4041 barrels of oil and 89MCF of gas per day. The combined output of nine previously hydro-fracked wells had improved from 3-4 barrels of oil and 6-8 MCF of gas per day to 9-10 barrels of oil and 34MCF of gas per day and the combined output of three previously shot wells had improved from 12 to 4-5 barrels per day at the end of 30 days.

  12. Hydrocarbon generation and brine migration in the central Appalachian basin

    SciTech Connect

    Evans, M.A. )

    1991-08-01

    Fluid inclusions in mineralized natural fractures from six Devonian shale cores were used to document hydrocarbon generation and brine migration in the central Appalachian basin. The sequence of formation of four regional fracture sets containing the inclusions was used to constrain the relative timing of fluid evolution. The earliest formed fluid inclusions are single-phase liquid inclusions containing a complex mixture of methane, ethane, higher hydrocarbons, and nitrogen. These inclusions formed during burial of the Devonian shales and early hydrocarbon generation in the oil window. As burial proceeded to a maximum and hydrocarbon generation entered the gas phase, later formed fluid inclusions record the presence of a more methane-rich fluid with minor ethane and nitrogen. Either during maximum burial or early uplift of the Devonian shale section, regional stress relaxation was accompanied by regional brine migration. Fluid inclusions record the influx of a methane-saturated, sodium chloride-rich brine and subsequent mixing with a presumably in situ-calcium-rich brine and subsequent mixing with a presumably in-situ calcium-rich brine. The migration pathway is presumed to be the Devonian shale detachment zone and underlying Devonian Oriskany Sandstone. This migration may be related to the fluids forming Mississippi Valley-type ore deposits. Present-day brine compositions reflect this ancient mixing. Brines from deep Cambrian through Silurian rocks are more calcium-chloride rich than brines from shallower Devonian and younger rocks. The sodium chloride-rich brines from Upper Devonian through Pennsylvanian rocks become more dilute as a result of mixing with meteoric water.

  13. Use of stable isotopes to identify sources of methane in Appalachian Basin shallow groundwaters: a review.

    PubMed

    Hakala, J Alexandra

    2014-09-20

    Development of unconventional shale gas reservoirs in the Appalachian Basin has raised questions regarding the potential for these activities to affect shallow groundwater resources. Geochemical indicators, such as stable carbon and hydrogen isotopes of methane, stable carbon isotopes of ethane, and hydrocarbon ratios, have been used to evaluate methane sources however their utility is complicated by influences from multiple physical (e.g., mixing) and geochemical (e.g., redox) processes. Baseline sampling of shallow aquifers prior to development, and measurement of additional geochemical indicators within samples from across the Appalachian Basin, may aid in identifying natural causes for dissolved methane in shallow groundwater versus development-induced pathways.

  14. Devonian shales of central Appalachian basin: geological controls on gas production

    SciTech Connect

    Lowry, P.H.; Hamilton-Smith, T.; Peterson, R.M. )

    1989-03-01

    Gas reserves of the Devonian shales of the Appalachian basin constitute a large, underdeveloped resource producing from fractured reservoirs. As part of ongoing Gas Research Institute research, K and A Energy Consultants, Inc., is identifying geological controls on gas production. Preliminary findings indicate that local gas production is controlled by a combination of structure and stratigraphy. Regional geological review indicates that Devonian sedimentation and structure is influenced by repeated reactivation of basement faults. Site-specific geologic studies indicate that depositional and structural mechanisms vary substantially throughout the basin. Gas production on the eastern margin of the producing area is controlled by an Alleghenian thrust front located by Grenville normal faults. High-capacity wells are associated with tear faults in the thrust sheets. To the southwest, deformation is controlled by both Grenville and Rome trough basement faults. Reactivation of these faults during later orogenic events produced a complex of high-angle reverse and strike-slip faults. Fracturing in the Devonian shales is produced by shearing and flexure associated with these structures. Syndepositional movement of the basement structures influenced the deposition of coarser grained turbidites and tempestites. The combination of fractures and coarser clastic beds provides effective reservoir systems. The shale contains abundant organic material consisting of terrestrial plant debris and marine algal remains. Thermal maturation of this material produced gas which charged the lower reservoir systems. Exploration along reactivated structural trends is an effective strategy for locating Devonian shale gas accumulations. This approach may also apply to other producing strata in the basin.

  15. Stratigraphic evidence from the Appalachian Basin for continuation of the Taconian orogeny into Early Silurian time

    NASA Astrophysics Data System (ADS)

    Ettensohn, Frank R.; Brett, Carlton E.

    2002-01-01

    Traditional interpretations of the Appalachian Basin during Silurian time suggest a period of tectonic stability between Taconian and Acadian orogenies. However, recent interpretations of evidence from deformation and igneous sources in the northern Appalachians indicate Silurian tectonism centered on and near the St. Lawrence promontory and that this tectonism probably effected sedimentation in parts of the Appalachian Basin during much of Silurian time. Of special interest is the tectonism that extended from latest Ordovician into Early Silurian time and the nature of its relationships with known orogenic events. Although evidence and interpretations from deformation and igneous sources have become increasingly well established, there has been little support from the stratigraphic record. Now, however, criteria based on the implications of flexural models, namely the nature and distribution of unconformities, the presence of flexural stratigraphic sequences, and the distribution in time and space of dark-shale-filled foreland basins, provide stratigraphic evidence from the Appalachian Basin that supports Early Silurian (Medinan; early Llandoverian) tectonism related to Taconian orogeny. In particular, the distribution and local angularity of the Ordovician-Silurian or Cherokee unconformity suggest major tectonic influence and a latest Ordovician to Early Silurian inception for that tectonism. An overlying flexural stratigraphic sequence represented by the Lower Silurian Medina Group and the presence of a dark-shale-filled foreland basin reflected by the Power Glen-lower Cabot Head shales support interpretations of flexural subsidence related to deformational loading. Moreover, the distribution in space and time of the foreland basin containing these shales indicates that the basin is more likely a continuation of the northwestwardly shifting trend of earlier Taconian basins than that of later Salinic basins. Although the kinematic regime may be different from

  16. Assessment of Undiscovered Oil and Gas Resources of the Appalachian Basin Province, 2002

    USGS Publications Warehouse

    Appalachian Basin Province Assessment Team: Milici, Robert C.; Ryder, Robert T.; Swezey, Christopher S.; Charpentier, Ronald R.; Cook, Troy A.; Crovelli, Robert A.; Klett, Timothy R.; Pollastro, Richard M.; Schenk, Christopher J.

    2003-01-01

    Using a geology-based assessment methodology, the U.S. Geological Survey estimated a mean of 70.2 trillion cubic feet of undiscovered natural gas, a mean of 54 million barrels of undiscovered oil, and a mean of 872 million barrels of undiscovered natural gas liquids in the Appalachian Basin Province.

  17. Gas Research Institute`s appalachian basin research: Selected bibliography. Topical report, July 1995

    SciTech Connect

    Picciano, L.

    1995-07-01

    The Appalachian Basin citations listed in this bibliography present select research reports that provide an overview of research and development (R&D) efforts related to the basin. The bibliography is organized in three sections, one for each of the following unconventional gas resources: coalbed methane, gas shales, and tight gas sands. Citations are further divided into geology and engineering subsections. The citations are only for those reports resulting directly from GRI`s research investment or reviews that extensively used GRI results.

  18. Eustatic and tectonic control of sedimentation in the Pennsylvanian strata of the Central Appalachian Basin

    SciTech Connect

    Chesnut, D.R. Jr. . Kentucky Geological Survey)

    1992-01-01

    Analysis of the Breathitt Group of the Central Appalachian Basin reveals three orders of depositional cycles or trends. The Breathitt coarsening-upward trend (20 million years (my)) represents increasing intensity of the Alleghenian Orogeny. The major transgression (MT) cycle (2.5 my) was controlled by an unknown eustatic or tectonic mechanism. The major coal beds and intervening strata make up the coal-clastic cycle (CC cycle) (=Appalachian cyclothem) which has a 0.4 my periodicity. This periodicity supports eustatic control of sedimentation modulated by an orbital periodicity. Extensive coastal peats deposited at lowstand (CC cycle) were preserved as coals, whereas highstand peats were eroded during the subsequent drop in sea level. Autocyclic processes such as delta switching and avulsion occurred within CC cycles. An Early Pennsylvanian unconformity represents uplift and erosion of mid-Carboniferous foreland basin deposits. Alluvial deposits (Breathitt Group) derived from the highlands were transported to the northwest toward the forebulge. During lowstand, the only outlet available to further sediment transport (Lee sandstones) was toward the southwest (Ouachita Trough), along the Black Warrior-Appalachian foreland basins. The Middle Pennsylvanian marks a period of intermittent overfilling of the foreland basin and cresting of the forebulge. Marine transgressions entered through the foreland basins and across saddles in the forebulge. After the Ouachita Trough was destroyed during the late Middle Pennsylvanian, marine transgressions migrated only across saddles in the forebulge. In the Late Pennsylvanian, marine waters entered the basin only across the diminished forebulge north of the Jessamine Dome.

  19. Sedimentology of gas-bearing Devonian shales of the Appalachian Basin

    SciTech Connect

    Potter, P.E.; Maynard, J.B.; Pryor, W.A.

    1981-01-01

    The Eastern Gas Shales Project (1976-1981) of the US DOE has generated a large amount of information on Devonian shale, especially in the western and central parts of the Appalachian Basin (Morgantown Energy Technology Center, 1980). This report summarizes this information, emphasizing the sedimentology of the shales and how it is related to gas, oil, and uranium. This information is reported in a series of statements each followed by a brief summary of supporting evidence or discussion and, where interpretations differ from our own, we include them. We believe this format is the most efficient way to learn about the gas-bearing Devonian shales of the Appalachian Basin and have organized our statements as follows: paleogeography and basin analysis; lithology and internal stratigraphy; paleontology; mineralogy, petrology, and chemistry; and gas, oil, and uranium.

  20. Coal resources of selected coal beds and zones in the Northern and Central Appalachian Basin

    USGS Publications Warehouse

    Ruppert, Leslie; Tewalt, Susan; Bragg, Linda

    2002-01-01

    The Appalachian Basin is one of the most important coal-producing regions in the world. Bituminous coal has been mined in the basin for the last three centuries, and the cumulative production is estimated at 34.5 billion short tons. Annual production in 1998 was about 452 million short tons; the basin's production is mostly in the northern (32 percent) and central (63 percent) coal regions. The coal is used primarily within the Eastern United States for electric power generation, but some of it is suitable for metallurgical uses. The U.S. Geological Survey (USGS) is completing a National Coal Resource Assessment of five coal-producing regions of the United States, including the Appalachian Basin. The USGS, in cooperation with the State geological surveys of Kentucky, Maryland, Ohio, Pennsylvania, Virginia, and West Virginia, has completed a digital coal resource assessment of five of the top-producing coal beds and coal zones in the northern and central Appalachian Basin coal regions -- the Pittsburgh coal bed, the Upper Freeport coal bed, the Fire Clay and Pond Creek coal zones, and the Pocahontas No. 3 coal bed. Of the 93 billion short tons of original coal in these units, about 66 billion short tons remain.

  1. 2000 resource assessment of selected coal beds and zones in the Northern and Central Appalachian Basin coal regions

    USGS Publications Warehouse

    Northern and Central Appalachian Basin Coal Regions Assessment Team

    2001-01-01

    This report includes results of a digital assessment of six coal beds or zones in the Northern and Central Appalachian Basin coal regions that produce over 15 percent of the Nation's coal. Other chapters include an executive summary, a report on geology and mining, a report summarizing other selected coal zones that were not assessed, and a report on USGS coal availability and recoverablity studies in the Northern and Central Appalachian Basin coal regions.

  2. Assessment of Appalachian Basin Oil and Gas Resources: Utica-Lower Paleozoic Total Petroleum System

    USGS Publications Warehouse

    Ryder, Robert T.

    2008-01-01

    The Utica-Lower Paleozoic Total Petroleum System (TPS) is an important TPS identified in the 2002 U.S. Geological Survey (USGS) assessment of undiscovered, technically recoverable oil and gas resources in the Appalachian basin province (Milici and others, 2003). The TPS is named for the Upper Ordovician Utica Shale, which is the primary source rock, and for multiple lower Paleozoic sandstone and carbonate units that are the important reservoirs. Upper Cambrian through Upper Silurian petroleum-bearing strata that constitute the Utica-Lower Paleozoic TPS thicken eastward from about 2,700 ft at the western margin of the Appalachian basin to about 12,000 ft at the thrust-faulted eastern margin of the Appalachian basin. The Utica-Lower Paleozoic TPS covers approximately 170,000 mi2 of the Appalachian basin from northeastern Tennessee to southeastern New York and from central Ohio to eastern West Virginia. The boundary of the TPS is defined by the following geologic features: (1) the northern boundary (from central Ontario to northeastern New York) extends along the outcrop limit of the Utica Shale-Trenton Limestone; (2) the northeastern boundary (from southeastern New York, through southeastern Pennsylvania-western Maryland-easternmost West Virginia, to northern Virginia) extends along the eastern limit of the Utica Shale-Trenton Limestone in the thrust-faulted eastern margin of the Appalachian basin; (3) the southeastern boundary (from west-central and southwestern Virginia to eastern Tennessee) extends along the eastern limit of the Trenton Limestone in the thrust-faulted eastern margin of the Appalachian basin; (4) the southwestern boundary (from eastern Tennessee, through eastern Kentucky, to southwestern Ohio) extends along the approximate facies change from the Trenton Limestone with thin black shale interbeds (on the east) to the equivalent Lexington Limestone without black shale interbeds (on the west); (5) the northern part of the boundary in southwestern Ohio

  3. Enhancement of the TORIS data base of Appalachian basin oil fields. Final report

    SciTech Connect

    1996-01-31

    The Tertiary Oil Recovery Information System, or TORIS, was developed by the Department of Energy in the early 1980s with a goal of accounting for 70% of the nation`s original oil in place (OOIP). More than 3,700 oil reservoirs were included in TORIS, but coverage in the Appalachian basin was poor. This TORIS enhancement project has two main objectives: to increase the coverage of oil fields in the Appalachian basin; and to evaluate data for reservoirs currently in TORIS, and to add, change or delete data as necessary. Both of these objectives have been accomplished. The geological surveys in Kentucky, Ohio, Pennsylvania and West Virginia have identified 113 fields in the Appalachian basin to be included in TORIS that collectively contained 80% of the original oil in place in the basin. Furthermore, data in TORIS at the outset of the project was checked and additional data were added to the original 20 TORIS oil fields. This final report is organized into four main sections: reservoir selection; evaluation of data already in TORIS; industry assistance; and data base creation and validation. Throughout the report the terms pool and reservoir may be used in reference to a single zone of oil accumulation and production within a field. Thus, a field is composed of one or more pools at various stratigraphic levels. These pools or reservoirs also are referred to as pay sands that may be individually named sandstones within a formation or group.

  4. Geographic information system (GIS)-based maps of Appalachian basin oil and gas fields: Chapter C.2 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ryder, Robert T.; Kinney, Scott A.; Suitt, Stephen E.; Merrill, Matthew D.; Trippi, Michael H.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    In 2006 and 2007, the greenline Appalachian basin field maps were digitized under the supervision of Scott Kinney and converted to geographic information system (GIS) files for chapter I.1 (this volume). By converting these oil and gas field maps to a digital format and maintaining the field names where noted, they are now available for a variety of oil and gas and possibly carbon-dioxide sequestration projects. Having historical names assigned to known digitized conventional fields provides a convenient classification scheme into which cumulative production and ultimate field-size databases can be organized. Moreover, as exploratory and development drilling expands across the basin, many previously named fields that were originally treated as conventional fields have evolved into large, commonly unnamed continuous-type accumulations. These new digital maps will facilitate a comparison between EUR values from recently drilled, unnamed parts of continuous accumulations and EUR values from named fields discovered early during the exploration cycle of continuous accumulations.

  5. Geologic Controls of Hydrocarbon Occurrence in the Appalachian Basin in Eastern Tennessee, Southwestern Virginia, Eastern Kentucky, and Southern West Virginia

    SciTech Connect

    Hatcher, Robert D

    2005-11-30

    This report summarizes the accomplishments of a three-year program to investigate the geologic controls of hydrocarbon occurrence in the southern Appalachian basin in eastern Tennessee, southwestern Virginia, eastern Kentucky, and southern West Virginia. The project: (1) employed the petroleum system approach to understand the geologic controls of hydrocarbons; (2) attempted to characterize the P-T parameters driving petroleum evolution; (3) attempted to obtain more quantitative definitions of reservoir architecture and identify new traps; (4) is worked with USGS and industry partners to develop new play concepts and geophysical log standards for subsurface correlation; and (5) geochemically characterized the hydrocarbons (cooperatively with USGS). Third-year results include: All project milestones have been met and addressed. We also have disseminated this research and related information through presentations at professional meetings, convening a major workshop in August 2003, and the publication of results. Our work in geophysical log correlation in the Middle Ordovician units is bearing fruit in recognition that the criteria developed locally in Tennessee and southern Kentucky are more extendible than anticipated earlier. We have identified a major 60 mi-long structure in the western part of the Valley and Ridge thrust belt that has been successfully tested by a local independent and is now producing commercial amounts of hydrocarbons. If this structure is productive along strike, it will be one of the largest producing structures in the Appalachians. We are completing a more quantitative structural reconstruction of the Valley and Ridge and Cumberland Plateau than has been made before. This should yield major dividends in future exploration in the southern Appalachian basin. Our work in mapping, retrodeformation, and modeling of the Sevier basin is a major component of the understanding of the Ordovician petroleum system in this region. Prior to our

  6. Assessment of Appalachian Basin Oil and Gas Resources: Carboniferous Coal-bed Gas Total Petroleum System

    USGS Publications Warehouse

    Milici, Robert C.

    2004-01-01

    The Carboniferous Coal-bed Gas Total Petroleum System, lies within the central and northern parts of the Appalachian coal field. It consists of five assessment units (AU): the Pocahontas Basin in southwestern Virginia, southern West Virginia, and eastern Kentucky, the Central Appalachian Shelf in Tennessee, eastern Kentucky and southern West Virginia, East Dunkard (Folded) in western Pennsylvania and northern West Virginia, West Dunkard (Unfolded) in Ohio and adjacent parts of Pennsylvania and West Virginia, and the Appalachian Anthracite and Semi-Anthracite AU in Pennsylvania and Virginia. Of these, only the Pocahontas Basin and West Dunkard (Folded) AU were assessed quantitatively by the U.S. Geological survey in 2002 as containing about 3.6 and 4.8 Tcf of undiscovered, technically recoverable gas, respectively (Milici and others, 2003). In general, the coal beds of this Total Petroleum System, which are both the source rock and reservoir, were deposited together with their associated sedimentary strata in Mississippian and Pennsylvanian (Carboniferous) time. The generation of biogenic (microbial) gas probably began almost immediately as the peat deposits were first formed. Microbial gas generation is probably occurring at present to some degree throughout the basin, where the coal beds are relatively shallow and wet. With sufficient depth of burial, compaction, and coalification during the late Paleozoic and Early Mesozoic, the coal beds were heated sufficiently to generate thermogenic gas in the eastern part of the Appalachian basin. Trap formation began initially with the deposition of the paleopeat deposits during the Mississippian, and continued into the Late Pennsylvanian and Permian as the Appalachian Plateau strata were deformed during the Alleghanian orogeny. 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

  7. Federally owned coal and Federal lands in the Northern and Central Appalachian Basin coal regions

    USGS Publications Warehouse

    Tewalt, S.J.

    2002-01-01

    The U.S. Geological Survey (USGS) assessed five coal beds or coal zones in the northern and central Appalachian Basin coal regions for the National Coal Resource Assessment: the Pittsburgh coal bed, the Upper Freeport coal bed, the Fire Clay coal zone, the Pond Creek coal zone, and the Pocahontas No. 3 coal bed. The assessment produced stratigraphic and geochemical databases and digital coal maps, or models, which characterized the coal beds and coal zones. Using the assessment models, the USGS estimated original and remaining (unmined) resources for these coal beds or zones. The Appalachian Basin assessment was conducted in collaboration with the State geological surveys of West Virginia, Pennsylvania, Ohio, Maryland, Kentucky, and Virginia.

  8. Upper Devonian transitional shale facies of western Appalachian basin of southeastern Ohio

    SciTech Connect

    Baranoski, M.T.; Riley, R.A.

    1987-09-01

    Transitional facies have been mapped in five Upper Devonian shale units using geophysical logs from southeastern Ohio. Each facies is a north-northeast-trending zone that parallels the paleodepositional strike of the Appalachian basin during the Late Devonian. The facies are defined by the interfingering of gray and greenish-gray siltstones and shales from the east with black shale from the west. Structure and isopach mapping indicate penecontemporaneous faulting and subsequent filling along faults with sediments in the form of coalescing lobate bodies. Penecontemporaneous faulting may be related to sediment loading of the Catskill delta. The relative position of the transitional facies may indicate the western penetration of far-distal turbidites of the Catskill delta into an anoxic portion of the Appalachian basin.

  9. Simulation of CO2 Sequestration and Enhanced Coalbed Methane Production in Multiple Appalachian Basin Coal Seams

    SciTech Connect

    Bromhal, G.S.; Siriwardane, H.J.; Gondle, R.K.

    2007-11-01

    A DOE-funded field injection of carbon dioxide is to be performed in an Appalachian Basin coal seam by CONSOL Energy and CNX Gas later this year. A preliminary analysis of the migration of CO2 within the Upper Freeport coal seam and the resulting ground movements has been performed on the basis of assumed material and geometric parameters. Preliminary results show that ground movements at the field site may be in a range that are measurable by tiltmeter technology.

  10. Feasibility study of heavy oil recovery in the Appalachian, Black Warrior, Illinois, and Michigan basins

    SciTech Connect

    Olsen, D.K.; Rawn-Schatzinger, V.; Ramzel, E.B.

    1992-07-01

    This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Appalachian, Black Warrior, Illinois, and Michigan basins cover most of the depositional basins in the Midwest and Eastern United States. These basins produce sweet, paraffinic light oil and are considered minor heavy oil (10{degrees} to 20{degrees} API gravity or 100 to 100,000 cP viscosity) producers. Heavy oil occurs in both carbonate and sandstone reservoirs of Paleozoic Age along the perimeters of the basins in the same sediments where light oil occurs. The oil is heavy because escape of light ends, water washing of the oil, and biodegradation of the oil have occurred over million of years. The Appalachian, Black Warrior, Illinois, and Michigan basins` heavy oil fields have produced some 450,000 bbl of heavy oil of an estimated 14,000,000 bbl originally in place. The basins have been long-term, major light-oil-producing areas and are served by an extensive pipeline network connected to refineries designed to process light sweet and with few exceptions limited volumes of sour or heavy crude oils. Since the light oil is principally paraffinic, it commands a higher price than the asphaltic heavy crude oils of California. The heavy oil that is refined in the Midwest and Eastern US is imported and refined at select refineries. Imports of crude of all grades accounts for 37 to >95% of the oil refined in these areas. Because of the nature of the resource, the Appalachian, Black Warrior, Illinois and Michigan basins are not expected to become major heavy oil producing areas. The crude oil collection system will continue to degrade as light oil production declines. The demand for crude oil will increase pipeline and tanker transport of imported crude to select large refineries to meet the areas` liquid fuels needs.

  11. Feasibility study of heavy oil recovery in the Appalachian, Black Warrior, Illinois, and Michigan basins

    SciTech Connect

    Olsen, D.K.; Rawn-Schatzinger, V.; Ramzel, E.B.

    1992-07-01

    This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Appalachian, Black Warrior, Illinois, and Michigan basins cover most of the depositional basins in the Midwest and Eastern United States. These basins produce sweet, paraffinic light oil and are considered minor heavy oil (10{degrees} to 20{degrees} API gravity or 100 to 100,000 cP viscosity) producers. Heavy oil occurs in both carbonate and sandstone reservoirs of Paleozoic Age along the perimeters of the basins in the same sediments where light oil occurs. The oil is heavy because escape of light ends, water washing of the oil, and biodegradation of the oil have occurred over million of years. The Appalachian, Black Warrior, Illinois, and Michigan basins' heavy oil fields have produced some 450,000 bbl of heavy oil of an estimated 14,000,000 bbl originally in place. The basins have been long-term, major light-oil-producing areas and are served by an extensive pipeline network connected to refineries designed to process light sweet and with few exceptions limited volumes of sour or heavy crude oils. Since the light oil is principally paraffinic, it commands a higher price than the asphaltic heavy crude oils of California. The heavy oil that is refined in the Midwest and Eastern US is imported and refined at select refineries. Imports of crude of all grades accounts for 37 to >95% of the oil refined in these areas. Because of the nature of the resource, the Appalachian, Black Warrior, Illinois and Michigan basins are not expected to become major heavy oil producing areas. The crude oil collection system will continue to degrade as light oil production declines. The demand for crude oil will increase pipeline and tanker transport of imported crude to select large refineries to meet the areas' liquid fuels needs.

  12. INNOVATIVE METHODOLOGY FOR DETECTION OF FRACTURE-CONTROLLED SWEET SPOTS IN THE NORTHERN APPALACHIAN BASIN

    SciTech Connect

    Robert Jacobi

    2005-05-31

    The primary goal was to enter Phase 2 by analyzing geophysical logs and sidewall cores from a verification well drilled into the Trenton/Black River section along lineaments. However, the well has not yet been drilled; Phase 2 has therefore not been accomplished. We have switched oil and gas exploration and production companies, and are now in continued negotiations with Fortuna concerning a plan to retrieve 18 m of horizontal core across a gas-charged zone in the Trenton/Black River in central New York State, the ''hottest'' play in the Appalachian Basin. We completed analysis of remote sensing images to determine, by using the weights-of-evidence method, which images and processing techniques result in lineaments that best reflect the fractures found in outcrop. The conclusions do not differ from the preliminary conclusions reported in the previous progress report. These data continue to demonstrate that integration of aeromagnetic and remote sensing lineaments, surface structure, and soil gas and seismic allows us to extrapolate Trenton-Black River trends away from confirmatory seismic lines.

  13. Thermal maturity map of Devonian shale in the Illinois, Michigan, and Appalachian basins of North America

    USGS Publications Warehouse

    East, Joseph A.; Swezey, Christopher S.; Repetski, John E.; Hayba, Daniel O.

    2012-01-01

    Much of the oil and gas in the Illinois, Michigan, and Appalachian basins of eastern North America is thought to be derived from Devonian shale that is within these basins (for example, Milici and others, 2003; Swezey, 2002, 2008, 2009; Swezey and others, 2005, 2007). As the Devonian strata were buried by younger sediments, the Devonian shale was subjected to great temperature and pressure, and in some areas the shale crossed a thermal maturity threshold and began to generate oil. With increasing burial (increasing temperature and pressure), some of this oil-generating shale crossed another thermal maturity threshold and began to generate natural gas. Knowledge of the thermal maturity of the Devonian shale is therefore useful for predicting the occurrence and the spatial distribution of oil and gas within these three basins. This publication presents a thermal maturity map of Devonian shale in the Illinois, Michigan, and Appalachian basins. The map shows outlines of the three basins (dashed black lines) and an outline of Devonian shale (solid black lines). The basin outlines are compiled from Thomas and others (1989) and Swezey (2008, 2009). The outline of Devonian shale is a compilation from Freeman (1978), Thomas and others (1989), de Witt and others (1993), Dart (1995), Nicholson and others (2004), Dicken and others (2005a,b), and Stoeser and others (2005).

  14. Geochemical analysis of crude oil from northern Appalachian, eastern Illinois, and southern Michigan basins

    SciTech Connect

    Noel, J.A.; Cole, J.; Innes, C.; Juzwick, S.

    1987-09-01

    In May 1986, the Ohio Board of Regents awarded a research grant to Ashland College to investigate the basinal origin of crude oil through trace-element analysis. The major thrust of the project was to attempt to finger print crude oils of various ages and depths from the northern Appalachian, eastern Illinois, and southern Michigan basins, to learn if the oldest crudes may have migrated among the basins. This in turn might give a more definitive time for the separation of the three basins. Nickel to vanadium ratios, were chosen to be the discriminators. Nickel to vanadium ratios show that the Trenton oil from the fields at Lima, Ohio; Oak Harbor in Ottawa County, Ohio; Urbana, Indiana; Peru, Indiana; and Albion, Michigan, are all different. The Trempealeau oils in Harmony and Lincoln Townships, Morrow County, are similar but they are different from those in Peru and Bennington Townships. The Devonian oils of the Illinois and Appalachian basins are distinctly different. The Berea oil shows little or no variability along strike. The Mississippian oils of the Illinois basin are different from the Berea oils and the Salem oil is different from the Chester. The only thing consistent about the Clinton is its inconsistency.

  15. Nested Paleozoic successor basins in the southern Appalachian Blue Ridge

    SciTech Connect

    Tull, J.F.; Groszos, M.S. )

    1990-11-01

    Field studies in the southern Appalachian Blue Ridge and its southwest extension, the Talladega belt, indicate that in at least three regions, polydeformed and metamorphosed turbidite-dominated sequences unconformably overlie rifted-margin continental-terrace wedge clastic rocks and overlying carbonate-platform deposits. These sequences are (1) the Talladega Group (in the Talladega belt), (2) the Walden Creek Group (along the west flank of the Blue Ridge), and (3) the Mineral Bluff Formation (within the core of the Blue Ridge). Paleontologic evidence indicates that the Talladega and Walden Creek Groups are in part as young as Silurian-Devonian. The presence of these anomalously young sequences unconformably above the trailing-margin stratigraphy in the Blue Ridge brings into question conventional ideas of the timing and nature of the tectonic evolution of the ancient continental margin.

  16. Apatite fission-track thermochronology of the central and southern Appalachian Basin

    SciTech Connect

    Roden, M.K.

    1989-01-01

    Samples were collected in west to east transects across the Appalachian Basin of Pennsylvania, Maryland, West Virginia, and Virginia. These samples locations were chosen to test the concept of increasing paleotemperature due to increasing burial from west to east across the Appalachian Basin and to detect any thermal anomalies that exist. Calculated time-temperature (tT) paths based on apatite fission-track apparent ages and confined track length distributions for samples from this study indicate that both the Pennsylvania and southern Appalachian had complex uplift and cooling histories. In Pennsylvania, the Tioga and Kalkberg ash bed samples from central Pennsylvania yield modelled tT paths that indicate early post-Alleghanian (285-270 Ma) cooling with uplift estimated at beginning at {approx}251 {plus minus} 25 Ma. Samples from the western Allegheny Plateau and Allegheny Front contain apatites which have reset to give fission-track ages and track lengths consistent with tT histories beginning at <200 Ma. In northeastern Pennsylvania on the Allegheny Plateau, the modelled tT paths show rapid cooling from temperatures in the range of 110{degree}-120{degree} C at 170-160 Ma. In the southern Appalachian Basin, calculated tT paths indicate that uplift in the northern section was immediately post-Alleghanian folding with uplift beginning first in the northwestern section on the Cumberland Plateau at {approx}226 {plus minus} 23 Ma and progressing to the eastern Valley and Ridge Province of Virginia at {approx}119 {plus minus} 12 Ma. The samples from southwestern Virginia yield a mean apatite fission-track apparent age of 175 {plus minus} 11 Ma which may be the result of a higher heat flow, higher paleogeothermal gradient during the Upper Jurassic-Early Cretaceous extension along the Atlantic Coast.

  17. Introduction to selected references on fossil fuels of the central and southern Appalachian basin: Chapter H.1 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ruppert, Leslie F.; Lentz, Erika E.; Tewalt, Susan J.; Román Colón, Yomayra A.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    The Appalachian basin contains abundant coal and petroleum resources that have been studied and extracted for at least 150 years. In this volume, U.S. Geological Survey (USGS) scientists describe the geologic framework and geochemical character of the fossil-fuel resources of the central and southern Appalachian basin. Separate subchapters (some previously published) contain geologic cross sections; seismic profiles; burial history models; assessments of Carboniferous coalbed methane and Devonian shale gas; distribution information for oil, gas, and coal fields; data on the geochemistry of natural gas and oil; and the fossil-fuel production history of the basin. Although each chapter and subchapter includes references cited, many historical or other important references on Appalachian basin and global fossil-fuel science were omitted because they were not directly applicable to the chapters.

  18. Allogenic processes, sediment flux, and Carboniferous stratigraphy in the Appalachian basin

    SciTech Connect

    Cecil, C.B.; Dulong, F.T.; Edgar, N.T. )

    1992-01-01

    The origin of Carboniferous strata in the central Appalachian basin is being evaluated as a function of paleoclimatic, eustatic, and tectonic processes. Of these processes, paleoclimate has, in the past, received the least attention but appears to be of primary importance as a control on stratigraphy. For example, Upper Mississippian strata include both marine carbonates and marine dark gray to black shales. The marine carbonate units are underlain and overlain by paleosols that contain calcic peds, pseudomorphs of gypsum, and rhizoconcretions with vertical root structures suggesting low soil moisture. The marine limestone generally is in sharp contact with an underlying paleosol. The lithostratigraphy of such a sequence is consistent with a transgressive-regressive cycle under relatively dry (semiarid) climatic conditions, which limits siliciclastic influx. In contrast, the marine gray and black shales are bounded by leached paleosols containing horizontal rhizomorphs and coal beds suggestive of wet soil conditions. Terrestrial organic matter in marine shales indicate relatively high terrestrial organic productivity, and the shale units are in gradational contact with underling strata. The lithostratigraphy of the marine shale sequences is consistent with deposition under relatively wet climatic regimes (probably seasonal and subhumid), which increased siliciclastic and terrestrial organic matter input. Relatively short-term climate cycles were a primary control on sediment flux within Carboniferous deposystems in the Appalachian basin. Long-term climate change also occurred as eastern North America moved from relatively dry latitudes of the southern hemisphere through the tropical rainy belt into drier latitudes of the northern hemisphere. Long-term tectonic change provided accommodation space. Such controls can readily be observed throughout Carboniferous strata in the Appalachian basin.

  19. Bituminous coal production in the Appalachian Basin; past, present, and future

    USGS Publications Warehouse

    Milici, R.C.

    1999-01-01

    This report on Appalachian basin coal production consists of four maps and associated graphs and tables, with links to the basic data that were used to construct the maps. Plate 1 shows the time (year) of maximum coal production, by county. For illustration purposes, the years of maximum production are grouped into decadal units. Plate 2 shows the amount of coal produced (tons) during the year of maximum coal production for each county. Plate 3 illustrates the cumulative coal production (tons) for each county since about the beginning of the 20th century. Plate 4 shows 1996 annual production by county. During the current (third) cycle of coal production in the Appalachian basin, only seven major coal-producing counties (those with more than 500 million tons cumulative production), including Greene County, Pa.; Boone, Kanawha, Logan, Mingo, and Monongalia Counties, W.Va.; and Pike County, Ky., exhibit a general increase in coal production. Other major coal-producing counties have either declined to a small percentage of their maximum production or are annually maintaining a moderate level of production. In general, the areas with current high coal production have large blocks of coal that are suitable for mining underground with highly efficient longwall methods, or are occupied by very large scale, relatively low cost surface mining operations. The estimated cumulative production for combined bituminous and anthracite coal is about 100 billion tons or less for the Appalachian basin. In general, it is anticipated that the remaining resources will be progressively of lower quality, will cost more to mine, and will become economical only as new technologies for extraction, beneficiation, and consumption are developed, and then only if prices for coal increase.

  20. Late Devonian glacigenic and associated facies from the central Appalachian Basin, eastern United States

    USGS Publications Warehouse

    Brezinski, D.K.; Cecil, C.B.; Skema, V.W.

    2010-01-01

    Late Devonian strata in the eastern United States are generally considered as having been deposited under warm tropical conditions. However, a stratigraphically restricted Late Devonian succession of diamictite- mudstonesandstone within the Spechty Kopf and Rockwell Formations that extends for more than 400 km along depositional strike within the central Appalachian Basin may indicate other wise. This lithologic association unconformably overlies the Catskill Formation, where a 3- to 5-m-thick interval of deformed strata occurs immediately below the diamictite strata. The diamictite facies consists of several subfacies that are interpreted to be subglacial, englacial, supraglacial meltout, and resedimented deposits. The mudstone facies that overlies the diamictite consists of subfacies of chaotically bedded, clast-poor mudstone, and laminated mudstone sub facies that represent subaqueous proximal debris flows and distal glaciolacustrine rhythmites or varvites, respectively. The pebbly sandstone facies is interpreted as proglacial braided outwash deposits that both preceded glacial advance and followed glacial retreat. Both the tectonic and depositional frameworks suggest that the facies were deposited in a terrestrial setting within the Appalachian foreland basin during a single glacial advance and retreat. Regionally, areas that were not covered by ice were subject to increased rainfall as indicated by wet-climate paleosols. River systems eroded deeper channels in response to sea-level drop during glacial advance. Marine facies to the west contain iceborne dropstone boulders preserved within contemporaneous units of the Cleveland Shale Member of the Ohio Shale.The stratigraphic interval correlative with sea-level drop, climate change, and glacigenic succession represents one of the Appalachian Basin's most prolific oil-and gas-producing intervals and is contemporaneous with a global episode of sea-level drop responsible for the deposition of the Hangenberg Shale

  1. Stratigraphic framework of Cambrian and Ordovician rocks across Rome Trough, central Appalachian basin

    SciTech Connect

    Ryder, R.T.

    1987-09-01

    Restored stratigraphic cross sections drawn primarily through the subsurface of parts of Pennsylvania, Ohio, West Virginia, Kentucky, and Tennessee provide new detailed information to further the understanding of Cambrian and Ordovician sedimentation and tectonics associated with the Rome trough sector of the Appalachian basin. Drilled thickness of the Cambrian and Ordovician sequence ranges from a maximum of about 14,500 ft (4.5 km) along the axis of the trough to a minimum of about 3500 ft (1 km) on the western flank.

  2. Diagenesis of Coeymans (Lower Devonian) patch reefs, northern Appalachian basin

    SciTech Connect

    Precht, W.F.

    1984-12-01

    Fourteen Coeymans-age patch reefs and biotherms have been identified along the Silurian-Devonian outcrop belt in northeastern Pennsylvania, northwestern New Jersey, and central New York. Detailed petrographic analysis of samples from five reefs has led to development of a regional diagenetic model. The model developed in this study leads us to infer that Coeymans reefs found in the shallow subsurface would not be favorable hydrocarbon reservoirs. The possibility does exist that localized porosity development occurs in untested reefs within the deeper subsurface portions of the basin.

  3. Geologic framework for the coal-bearing rocks of the Central Appalachian Basin

    USGS Publications Warehouse

    Chesnut, D.R.

    1996-01-01

    Coal production has been an important economic factor in the Central Appalachian Basin. However, regional stratigraphic and structural relationships of the coal-bearing rocks of the basin have been poorly understood due to numerous separate nomenclatural schemes employed by various states. In order to estimate coal resources and understand mechanisms controlling the distribution of coal within the basin, a reliable geologic framework is necessary. Seven detailed cross sections across the Central Appalachian Basin were constructed in order to examine the stratigraphic and structural framework of the coal-bearing rocks in the basin. The cross sections were based on more than 1000 oil and gas well logs, measured sections, and borehole information from Kentucky, Ohio, Tennessee, Virginia and West Virginia. The cross sections revealed three main points discussed here: southeast thickening of the Pennsylvanian strata, unconformable northwestward onlapping relationship of Lower Pennsylvanian strata over underlying Lower Pennsylvanian and Mississippian strata and regional continuity of beds. The cross sections, geologic mapping, coal-resource studies, extensive new highway exposures and the occurrence of tonstein beds indicate that many coal beds and marine strata are laterally extensive, albeit locally variable across the basin. Certain quartzose sandstone bodies are also extensive over large areas of the basin. Existing stratigraphic nomenclature schemes obscured the geologic framework of the basin, so a new unified nomenclature scheme was devised to better describe stratigraphic features of the basin. The new stratigraphic nomenclature, now only formalized for Kentucky, was based on key stratigraphic units that proved to be extensive across the basin. Lower and Middle Pennsylvanian rocks are now recognized as the Breathitt Group (the Breathitt Formation was elevated to group rank). The Breathitt Group was subdivided into eight coal-bearing formations by relatively thick

  4. Sequence stratigraphy and depositional systems of the Lower Silurian Medina Group, northern Appalachian basin

    SciTech Connect

    Castle, J.W. )

    1991-08-01

    Detailed sedimentological analysis of 3500 ft of continuous core from 44 wells in Pennsylvania, Ohio, Ontario, New York, and West Virginia, combined with regional study of geophysical logs, results in new interpretations of sequence stratigraphy and depositional systems in Lower Silurian siliciclastic rocks of the northern Appalachian basin. Above a type-1 sequence boundary at the base of the Medina Group are a lowstand systems tract and a transgressive systems tract that are represented, respectively, by the Whirlpool Sandstone and by the overlying Cabot Head Shale. The thickest sandstones in the Medina Group occur in the Grimsby Sandstone, which is interpreted as a highstand systems tract with basinward-prograding parasequences. Sea level rise after Grimsby parasequence deposition is represented by marine-shelf shale in the uppermost part of the Medina Group. Based on facies successions in the cores, four mappable depositional systems are interpreted for the Grimsby Sandstone and correlative sandstone units; (1) wave-dominated middle shelf, (2) wave- and tide-influenced inner shelf, (3) tide dominated shoreline, and (4) fluvial. The wave-dominated middle-shelf system, which includes very fine-grained shelf-ridge sandstones encased in marine shale, is the most basinward system, occurring from Ontario through parts of eastern Ohio. Shoreward, across the northern Appalachian basin, the influence of tidal processes relative to wave processes generally increased, which may have been related to distance across the shelf, water depth, and shoreline configuration. The shoreline may have been deltaic in some areas and straight in other areas.

  5. Central Appalachian basin natural gas database: distribution, composition, and origin of natural gases

    USGS Publications Warehouse

    Román Colón, Yomayra A.; Ruppert, Leslie F.

    2015-01-01

    The U.S. Geological Survey (USGS) has compiled a database consisting of three worksheets of central Appalachian basin natural gas analyses and isotopic compositions from published and unpublished sources of 1,282 gas samples from Kentucky, Maryland, New York, Ohio, Pennsylvania, Tennessee, Virginia, and West Virginia. The database includes field and reservoir names, well and State identification number, selected geologic reservoir properties, and the composition of natural gases (methane; ethane; propane; butane, iso-butane [i-butane]; normal butane [n-butane]; iso-pentane [i-pentane]; normal pentane [n-pentane]; cyclohexane, and hexanes). In the first worksheet, location and American Petroleum Institute (API) numbers from public or published sources are provided for 1,231 of the 1,282 gas samples. A second worksheet of 186 gas samples was compiled from published sources and augmented with public location information and contains carbon, hydrogen, and nitrogen isotopic measurements of natural gas. The third worksheet is a key for all abbreviations in the database. The database can be used to better constrain the stratigraphic distribution, composition, and origin of natural gas in the central Appalachian basin.

  6. Structural controls on fractured coal reservoirs in the southern Appalachian Black Warrior foreland basin

    USGS Publications Warehouse

    Groshong, R.H.; Pashin, J.C.; McIntyre, M.R.

    2009-01-01

    Coal is a nearly impermeable rock type for which the production of fluids requires the presence of open fractures. Basin-wide controls on the fractured coal reservoirs of the Black Warrior foreland basin are demonstrated by the variability of maximum production rates from coalbed methane wells. Reservoir behavior depends on distance from the thrust front. Far from the thrust front, normal faults are barriers to fluid migration and compartmentalize the reservoirs. Close to the thrust front, rates are enhanced along some normal faults, and a new trend is developed. The two trends have the geometry of conjugate strike-slip faults with the same ??1 direction as the Appalachian fold-thrust belt and are inferred to be the result of late pure-shear deformation of the foreland. Face cleat causes significant permeability anisotropy in some shallow coal seams but does not produce a map-scale production trend. ?? 2008 Elsevier Ltd. All rights reserved.

  7. Determining the source and genetic fingerprint of natural gases using noble gas geochemistry: a northern Appalachian Basin case study

    USGS Publications Warehouse

    Hunt, Andrew G.; Darrah, Thomas H.; Poreda, Robert J.

    2012-01-01

    Silurian and Devonian natural gas reservoirs present within New York state represent an example of unconventional gas accumulations within the northern Appalachian Basin. These unconventional energy resources, previously thought to be noneconomically viable, have come into play following advances in drilling (i.e., horizontal drilling) and extraction (i.e., hydraulic fracturing) capabilities. Therefore, efforts to understand these and other domestic and global natural gas reserves have recently increased. The suspicion of fugitive mass migration issues within current Appalachian production fields has catalyzed the need to develop a greater understanding of the genetic grouping (source) and migrational history of natural gases in this area. We introduce new noble gas data in the context of published hydrocarbon carbon (C1,C2+) (13C) data to explore the genesis of thermogenic gases in the Appalachian Basin. This study includes natural gases from two distinct genetic groups: group 1, Upper Devonian (Marcellus shale and Canadaway Group) gases generated in situ, characterized by early mature (13C[C1  C2][13C113C2]: –9), isotopically light methane, with low (4He) (average, 1  103 cc/cc) elevated 4He/40Ar and 21Ne/40Ar (where the asterisk denotes excess radiogenic or nucleogenic production beyond the atmospheric ratio), and a variable, atmospherically (air-saturated–water) derived noble gas component; and group 2, a migratory natural gas that emanated from Lower Ordovician source rocks (i.e., most likely, Middle Ordovician Trenton or Black River group) that is currently hosted primarily in Lower Silurian sands (i.e., Medina or Clinton group) characterized by isotopically heavy, mature methane (13C[C1 – C2] [13C113C2]: 3), with high (4He) (average, 1.85  103 cc/cc) 4He/40Ar and 21Ne/40Ar near crustal production levels and elevated crustal noble gas content (enriched 4He,21Ne, 40Ar). Because the release of each crustal noble gas (i.e., He, Ne, Ar

  8. Palynology of late Middle Pennsylvanian coal beds in the Appalachian Basin

    USGS Publications Warehouse

    Eble, C.F.

    2002-01-01

    Fossil spores and pollen have long been recognized as valuable tools for identifying and correlating coal beds. This paper describes the palynology of late Middle Pennsylvanian coal beds in the Appalachian Basin with emphasis on forms that assist both intra- and interbasinal coal bed correlation. Stratigraphically important palynomorphs that originate in late Middle Pennsylvanian strata include Torispora securis, Murospora kosankei, Triquitrites minutus, Cadiospora magna, Mooreisporites inusitatus, and Schopfites dimorphus. Taxa that terminate in the late Middle Pennsylvanian include Radiizonates difformis, Densosporites annulatus, Dictyotriletes bireticulatus, Vestispora magna, and Savitrisporites nux. Species of Lycospora, Cirratriradites, Vestispora, and Thymospora, as well as Granasporites medius, Triquitrites sculptilis, and T. securis and their respective ranges slightly higher, in earliest Late Pennsylvanian age strata. Late Middle Pennsylvanian and earliest Late Pennsylvanian strata in the Appalachian Basin correlate with the Radiizonates difformis (RD), Mooreisporites inusitatus (MI), Schopfites colchesterensis-S. dimorphus (CP), and Lycospora granulata-Granasporites medius (GM) spore assemblage zones of the Eastern Interior, or Illinois Basin. In the Western Interior Basin, these strata correlate with the middle-upper portion of the Torispora securis-Laevigatosporites globosus (SG) and lower half of the Thymospora pseudothiessenii-Schopfites dimorphus (PD) assemblage zones. In western Europe, late Middle Pennsylvanian and earliest Late Pennsylvanian strata correlate with the middle-upper portion of the Torispora securis-T. laevigata (SL) and the middle part of the Thymospora obscura-T. thiessenii (OT) spore assemblage zones. Allegheny Formation coal beds also correlate with the Torispora securis (X) and Thymospora obscura (XI) spore assemblages, which were developed for coal beds in Great Britain. ?? 2002 Elsevier Science B.V. All rights reserved.

  9. Geology, exploration status of Uruguay's sedimentary basins

    SciTech Connect

    Goso, C.; Santa Ana, H. de )

    1994-02-07

    This article attempts to present the geological characteristics and tectonic and sedimentary evolution of Uruguayan basins and the extent to which they have been explored. Uruguay is on the Atlantic coast of South America. The country covers about 318,000 sq km, including offshore and onshore territories corresponding to more than 65% of the various sedimentary basins. Four basins underlie the country: the Norte basin, the Santa Lucia basin, the offshore Punta del Este basin, and the offshore-onshore Pelotas-Merin basin. The Norte basin is a Paleozoic basin while the others are Mesozoic basins. Each basin has been explored to a different extent, as this paper explains.

  10. Geologic controls on thermal maturity patterns in Pennsylvanian coal-bearing rocks in the Appalachian basin

    USGS Publications Warehouse

    Ruppert, L.F.; Hower, J.C.; Ryder, R.T.; Levine, J.R.; Trippi, M.H.; Grady, W.C.

    2010-01-01

    Thermal maturation patterns of Pennsylvanian strata in the Appalachian basin were determined by compiling and contouring published and unpublished vitrinite reflectance (VR) measurements. VR isograd values range from 0.6% in eastern Ohio and eastern Kentucky (western side of the East Kentucky coal field) to greater than 5.5% in eastern Pennsylvania (Southern Anthracite field, Schuylkill County), corresponding to ASTM coal rank classes of high volatile C bituminous to meta-anthracite. VR isograds show that thermal maturity of Pennsylvanian coals generally increases from west to east across the basin. The isograds patterns, which are indicative of maximum temperatures during burial, can be explained by variations in paleodepth of burial, paleogeothermal gradient, or a combination of both. However, there are at least four areas of unusually high-rank coal in the Appalachian basin that depart from the regional trends and are difficult to explain by depth of burial alone: 1) a west-northwestward salient centered in southwestern Pennsylvania; 2) an elliptically-shaped, northeast-trending area centered in southern West Virginia and western Virginia; 3) the eastern part of Black Warrior coal field, Alabama; and 4) the Pennsylvania Anthracite region, in eastern Pennsylvania. High-rank excursions in southwest 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 higher heat flow from fluids, the Pennsylvania Anthracite region also experienced greater depth of burial. The high-rank excursion in southwest Virginia was probably primarily controlled by overburden thickness, but may also have been influenced by higher geothermal gradients.

  11. INNOVATIVE METHODOLOGY FOR DETECTION OF FRACTURE-CONTROLLED SWEET SPOTS IN THE NORTHERN APPALACHIAN BASIN

    SciTech Connect

    Robert Jacobi; John Fountain

    2005-03-01

    The primary goal was to enter Phase 2 by analyzing geophysical logs and sidewall cores from a verification well drilled into the Trenton/Black River section along lineaments. However, the well has not yet been drilled; Phase 2 has therefore not been accomplished. We have switched oil and gas exploration and production companies, and are now, in conjunction with Fortuna, planning to retrieve 18 m of horizontal core across a gas-charged zone in the Trenton/Black River in central New York State, the ''hottest'' play in the Appalachian Basin. Secondary goals in Phase I were also completed in previous reporting period. Although new structural data were collected and analyzed for a few regions where we had no data, the results did not change the previous conclusions. We have also continued analyzing remote sensing images to determine, by using the weights-of-evidence method, which images and processing techniques result in lineaments that best reflect the fractures found in outcrop. We have tested the lineaments from EarthSat (1997), as well as lineaments we identified on Landsat and ASTER images. For fracture intensification domains (FIDs) along Seneca Lake, we found that lineaments identified on a fused image of Landsat and ASTER images produced better correlation to FIDs than lineaments from EarthSat (1997) and ASTER alone. This relationship held true for all orientations of FIDs except E-striking FIDs, which showed a better correlation with lineaments observed on ASTER lineaments than on the fused Landsat and ASTER image lineaments. For Cayuga Lake FIDs, lineaments identified on a fused image of Landsat and ASTER images also produced significantly better correlation to FIDs than lineaments from ASTER alone for NW- and NNW-striking FIDs. However, for NE-, ENE- and E-striking FIDs, ASTER lineaments generally showed the closest match. These data continue to demonstrate that integration of aeromagnetic and remote sensing lineaments, surface structure, soil gas and

  12. Stratigraphic analysis of the carboniferous rocks of the Central Appalachian Basin

    SciTech Connect

    Chesnut, D.R. Jr.

    1988-01-01

    A series of seven cross sections was constructed across part of the Central Appalachian Basin in Kentucky, Tennessee, Virginia, West Virginia, and Ohio. Information used to make these sections included well logs, coal-company core descriptions, measured sections, and mapped surface geology. Newly discovered surface and subsurface structural features such as faults, folds, and flexures, are described. A new, unofficial lithostratigraphic nomenclature was introduced to illustrate the stratigraphic framework, and a regional unconformity was interpreted to occur between the Pennsylvanian Pocahontas Formation and the Pennsylvanian New River Formation. The cross sections reveal that sequential truncation of formations below the unconformity occurs t the northwest in the basin. A regional unconformity and biostratigraphic evidence indicate that the Carboniferous rocks were deposited in a series of several small-scale environmental continua. Pennsylvanian rocks overlying the regional unconformity sequentially overlap the underlying rocks to the northwest in the basin. Belts of quartzose sandstones (Lee Formation) within the overlying rocks, are oriented northeast-southwest. Succeeding sandstone belts onlap the unconformity to the northwest within the basin. A fluvial origin is suggested for the quartzose, conglomeratic sands of the Lee Formation. The source for these sands may have been reworked sediments derived from the Old Red Sandstone continent to the northwest in Canada. The remaining Pennsylvanian coal-bearing clastic rocks (Breathitt Group) were deposited as clastic wedges derived from the east and southeast on coastal lowlands.

  13. Nature, origin, and production characteristics of the Lower Silurian regional oil and gas accumulation, central Appalachian basin, United States

    USGS Publications Warehouse

    Ryder, R.; Zagorski, W.A.

    2003-01-01

    Low-permeability sandstones of the Lower Silurian regional oil and gas accumulation cover about 45,000 mi2 (117,000 km2) of the Appalachian basin and may contain as much as 30 tcf of recoverable gas resources. Major reservoirs consist of the "Clinton" sandstone and Medina Group sandstones. The stratigraphically equivalent Tuscarora Sandstone increases the area of the Lower Silurian regional accumulation (LSRA) by another 30,000 mi2 (78,000 km2). Approximately 8.7 tcf of gas and 400 million bbl of oil have been produced from the Clinton/Medina reservoirs since 1880. The eastern predominantly gas-bearing part of the LSRA is a basin-center gas accumulation, whereas the western part is a conventional oil and gas accumulation with hybrid features of a basin-center accumulation. The basin-center accumulations have pervasive gas saturation, water near irreducible saturation, and generally low fluid pressures. In contrast, the hybrid-conventional accumulations have less-pervasive oil and gas saturation, higher mobile-water saturation, and both normal and abnormally low fluid pressures. High mobile-water saturation in the hybrid-conventional reservoirs form the updip trap for the basin-center gas creating a broad transition zone, tens of miles wide, that has characteristics of both end-member accumulation types. Although the Tuscarora Sandstone part of the basin-center gas accumulation is pervasively saturated with gas, most of its constituent sandstone beds have low porosity and permeability. Commercial gas fields in the Tuscarora Sandstone are trapped in naturally fractured, faulted anticlines. The origin of the LSRA includes (1) generation of oil and gas from Ordovician black shales, (2) vertical migration through an overlying 1000-ft (305-m)-thick Ordovician shale; (3) abnormally high fluid pressure created by oil-to-gas transformation; (4) updip displacement of mobile pore water by overpressured gas; (5) entrapment of pervasive gas in the basin center; (6) postorogenic

  14. Geologic summary of the Appalachian Basin, with reference to the subsurface disposal of radioactive waste solutions

    USGS Publications Warehouse

    Colton, G.W.

    1962-01-01

    The Appalachian basin is an elongate depression in the crystalline basement complex< which contains a great volume of predominantly sedimentary stratified rocks. As defined in this paper it extends from the Adirondack Mountains in New York to central Alabama. From east to west it extends from the west flank of the Blue Ridge Mountains to the crest of the Findlay and Cincinnati arches and the Nashville dome. It encompasses an area of about 207,000 square miles, including all of West Virginia and parts of New York, New Jersey, Pennsylvania, Ohio, Maryland, Virginia, Kentucky, Tennessee, North Carolina, Georgia, and Alabama. The stratified rocks that occupy the basin constitute a wedge-shaped mass whose axis of greatest thickness lies close to and parallel to the east edge of the basin. The maximum thickness of stratified rocks preserved in any one part of the basin today is between 35,000 and 40,000 feet. The volume of the sedimentary rocks is approximately 510,000 cubic miles and of volcanic rocks is a few thousand cubic miles. The sedimentary rocks are predominantly Paleozoic in age, whereas the volcanic rocks are predominantly Late Precambrian. On the basis of gross lithology the stratified rocks overlying the crystalline basement complex can be divided into nine vertically sequential units, which are designated 'sequences' in this report. The boundaries between contiguous sequences do not necessarily coincide with the commonly recognized boundaries between systems or series. All sequences are grossly wedge shaped, being thickest along the eastern margin of the basin and thinnest along the western margin. The lowermost unit--the Late Precambrian stratified sequence--is present only along part of the eastern margin of the basin, where it lies unconformably on the basement complex. It consists largely of volcanic tuffs and flows but contains some interbedded sedimentary rocks. The Late Precambrian sequence is overlain by the Early Cambrian clastic sequence. Where

  15. Linked sequence development and global climate change: The Upper Mississippian record in the Appalachian basin

    SciTech Connect

    Miller, D.J.; Eriksson, K.A.

    1999-01-01

    The character and relative stratigraphic position of paleoclimatic indicators within Upper Mississippian strata of southern West Virginia suggest a link between eustasy and patterns of continental- to global-scale atmospheric circulation. At the cyclothem scale, annual rhythms in marine facies, and paleovertisols and lacustrine carbonates in terrestrial units indicate that seasonal, semiarid climatic conditions prevailed during highstand progradation. In contrast, leached paleosols and coals that underlie sequence boundaries and occur within transgressive heterolithic facies are suggestive of humid climatic conditions during late highstand through early transgression. Milankovitch-band, glacial-interglacial cyclicity may explain both sequence development and the evidence for Late Mississippian climate fluctuations in the Appalachian basin. Shifts from seasonal to humid climatic conditions are attributed to systematic variation in monsoonal circulation, whereby seasonal moisture became restricted to the equatorial belt during the lowstands of each {approximately}400 k.y. glacial-interglacial cycle.

  16. Distribution of maximum burial temperatures across northern Appalachian Basin and implications for Carboniferous sedimentation patterns

    SciTech Connect

    Johnsson, M.J.

    1986-05-01

    Clay-mineral diagenesis and apatite fission-track age data indicate that the maximum burial temperatures to which the Middle Devonian Tioga metabentonite was exposed rise abruptly from low values in western New York State to higher values in the east. The highest temperatures, which approach 175/sup 0/C, were reached just west of Syracuse. Neither the pattern nor the magnitude of burial temperatures can be explained solely by burial of the metabentonite beneath Upper Devonian sediments. Although spatial variations in the geothermal gradient could have produced the observed pattern of burial temperatures, it is more likely that Carboniferous sediments, no longer preserved in the area, were responsible for the indicated burial. The inferred presence of thick Carboniferous sequences in western New York State suggests that the Allegheny orogeny had a stronger influence on sedimentation in the northern Appalachian Basin than has been previously recognized. 25 references, 2 figures, 2 tables.

  17. Munsell color value as related to organic carbon in Devonian shale of Appalachian basin

    USGS Publications Warehouse

    Hosterman, J.W.; Whitlow, S.I.

    1981-01-01

    Comparison of Munsell color value with organic carbon content of 880 samples from 50 drill holes in Appalachian basin shows that a power curve is the best fit for the data. A color value below 3 to 3.5 indicates the presence of organic carbon but is meaningless in determining the organic carbon content because a large increase in amount of organic carbon causes only a minor decrease in color value. Above 4, the color value is one of the factors that can be used in calculating the organic content. For samples containing equal amounts of organic carbon, calcareous shale containing more than 5% calcite is darker than shale containing less than 5% calcite.-Authors

  18. Geologic Controls of Hydrocarbon Occurrence in the Southern Appalachian Basin in Eastern Tennessee, Southwestern Virginia, Eastern Kentucky, and Southern West Virginia

    SciTech Connect

    Robert D. Hatcher

    2004-05-31

    This report summarizes the second-year accomplishments of a three-year program to investigate the geologic controls of hydrocarbon occurrence in the southern Appalachian basin in eastern Tennessee, southwestern Virginia, eastern Kentucky, and southern West Virginia. The project: (1) employs the petroleum system approach to understand the geologic controls of hydrocarbons; (2) attempts to characterize the T-P parameters driving petroleum evolution; (3) attempts to obtain more quantitative definitions of reservoir architecture and identify new traps; (4) is working with USGS and industry partners to develop new play concepts and geophysical log standards for subsurface correlation; and (5) is geochemically characterizing the hydrocarbons (cooperatively with USGS). Second-year results include: All current milestones have been met and other components of the project have been functioning in parallel toward satisfaction of year-3 milestones. We also have been effecting the ultimate goal of the project in the dissemination of information through presentations at professional meetings, convening a major workshop in August 2003, and the publication of results. Our work in geophysical log correlation in the Middle Ordovician units is bearing fruit in recognition that the criteria developed locally in Tennessee and southern Kentucky have much greater extensibility than anticipated earlier. We have identified a major 60 mi-long structure in the western part of the Valley and Ridge thrust belt that is generating considerable exploration interest. If this structure is productive, it will be one of the largest structures in the Appalachians. We are completing a more quantitative structural reconstruction of the Valley and Ridge than has been made before. This should yield major dividends in future exploration in the southern Appalachian basin. Our work in mapping, retrodeformation, and modeling of the Sevier basin is a major component of the understanding of the Ordovician

  19. Appalachian basin bituminous coal: sulfur content and potential sulfur dioxide emissions of coal mined for electrical power generation: Chapter G.5 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Trippi, Michael H.; Ruppert, Leslie F.; Attanasi, E.D.; Milici, Robert C.; Freeman, P.A.

    2014-01-01

    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.

  20. Petroleum evaluation of Ordovician black shale source rocks in northern Appalachian basin

    SciTech Connect

    Wallace, L.G.; Roen, J.B.

    1988-08-01

    A preliminary appraisal of the Ordovician black shale source beds in the northern part of the Appalachian basin shows that the sequence is composed of the Upper Ordovician Utica Shale and its correlatives. The shales range in thickness from less than 200 ft in the west to more than 600 ft in the east along the Allegheny Front. Structure contours indicate that the shales plunge from 2,000 ft below sea level in central Ohio and to about 12,000 ft below sea level in central and northeastern Pennsylvania. Geochemical analyses of 175 samples indicate that the sequence has an average total organic carbon content (TOC) of 1.34%. Conodont alteration indices (CAI) and production indices indicate that the stages of maturation range from diagenetic in the less deeply buried western part of the basin, which probably produced mostly oil, to catagenetic in the more deeply buried eastern part of the basin, which probably produced mostly gas. Potential for continued hydrocarbon generation is poor in the east and fair to moderate in the western part of the basin. If the authors assume that these rocks have produced hydrocarbons, the hydrocarbons have since migrated. Using an average TOC of 1%, an organic carbon to hydrocarbon conversion factor of 10%, and a volume of rock within the oil and gas generation range as defined by CAI values of 1.5-4, the Ordovician shale could have generated 165 billion bbl of oil or equivalent. If only 1% of the 165 billion bbl was trapped after migration, then 1.65 billion bbl of oil or equivalent would be available for discovery.

  1. Geohydrologic feasibility study of the Northern and Central Appalachian basin areas for the potential application of a production process patented by Jack W. McIntyre

    SciTech Connect

    Kvasnicka, D.

    1994-03-01

    Geraghty & Miller, Inc. of Midland, Texas conducted geologic and hydrologic feasibility studies of the potential applicability of a patented (US Patent Office No. 4,766,957) process developed by Jack W. McIntyre for the recovery of natural gas from coalbed/sand formations in the Northern and Central Appalachian basin areas. General research, based on a review of published literature from both public and private sources, indicates that the generally thin, but numerous coalbeds found in the greater Appalachian Basin area do exhibit some potential for the application of this patented process. Estimates of total gas reserves in-place (Gas Research Institute, July 1991) for coalbeds in the Central and Northern Appalachian Basin areas are 5 trillion cubic feet (TCF) and 61 TCF respectively. Produced waters associated with coal deposits in the greater Appalachian Basin area can be characterized on the basis of established but limited production of coalbed methane. Central Appalachian coals generally produce small quantities of water (less than 50 barrels of water per day for the average producing well) which is high in total dissolved solids (TDS), greater than 30,000 parts per million (ppM). The chemical quality of water produced from these coal seams represents a significant disposal challenge to the operators of methane-producing wells in the Central Appalachian Basin. By contrast, water associated with the production of coalbed methane in the Northern Appalachian Basin is generally fair to good quality, and daily production volumes are low. However, the relatively slow desorption of methane gas from Northern Appalachian coals may result in a greater net volume of produced water over the economic life of the well. The well operator must respond to long-term disposal needs.

  2. Vertical movements of the crust: Case histories from the northern Appalachian Basin

    NASA Astrophysics Data System (ADS)

    Friedman, Gerald M.

    1987-12-01

    Evidence of former deep burial of Ordovician to Devonian strata of the northern Appalachian Basin has been obtained from various techniques of study, including fluid-inclusion homogenization temperatures, δ18O, and vitrinite reflectance. Diagenetic minerals indicate paleotemperatures of 100 200 °C. Maximum depths of burial were calculated from the estimated paleotemperatures; a gradient of 26 °C/km was assumed. Silurian strata of the basin are interpreted to have reached maximum burial depths of 5.0 km; Devonian strata in the Catskill Mountains had former burial depths of ˜6.5 km; Lower Ordovician carbonate sequences were buried to >7 km; Middle Ordovician strata had paleodepths of ˜5 km; and Devonian carbonate strata had paleodepths from 4.5 to 5 km. If these strata were buried deeper than previously thought, unexpectedly large amounts of uplift and erosion, ranging from 4.3 to 7 km, must also have taken place to bring these strata to the present land surface. The occurrence of such large-scale vertical movements of the crust and lithosphere must be recognized in paleogeographic reconstructions. Such drastic changes represent isostatic unroofing, with widespread implications for paleogeography of a kind unrecognized at present.

  3. Lithologic and environmental atlas of Berea Sandstone (Mississippian) in the Appalachian Basin

    NASA Astrophysics Data System (ADS)

    Potter, P. E.; Maynard, J. B.; Jackson, D.; Dereamer, J.

    1984-01-01

    The Berea Sandstone occurs throughout much of the Appalachian Basin where it is an oil and gas reservoir and is quarried as a building stone. Because of its uniform porosity and permeability in the quarries at South Amherst, Ohio, it has been used by petroleum engineers in North America as a model reservoir sandstone. Currently, the Berea is locally classified as a light gas sand. Six outcrops and 22 cores of the Berea are described. These descriptions are accompanied by wireline logs of the Berea section in the core holes and gamma ray profiles of outcrops to help explorationists, reservoir geologists, and petroleum engineers better interpret the lithology and depositional environments represented by the many thousands of wireline logs in the Applachian Basin. The depositional environments likely to occur in the Berea are briefly described and the various sedimentary structures of the Berea are illustrated so that it can be seen in both outcrops and cores, carefully documents vertical profiles of grain size and sedimentary structures, and concludes with a summary of unresolved problems.

  4. Geographic information system (GIS)-based maps of Appalachian basin oil and gas fields: Chapter C.2 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ryder, Robert T.; Kinney, Scott A.; Suitt, Stephen E.; Merrill, Matthew D.; Trippi, Michael H.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    In 2006 and 2007, the greenline Appalachian basin field maps were digitized under the supervision of Scott Kinney and converted to geographic information system (GIS) files for chapter I.1 (this volume). By converting these oil and gas field maps to a digital format and maintaining the field names where noted, they are now available for a variety of oil and gas and possibly carbon-dioxide sequestration projects. Having historical names assigned to known digitized conventional fields provides a convenient classification scheme into which cumulative production and ultimate field-size databases can be organized. Moreover, as exploratory and development drilling expands across the basin, many previou

  5. Early to Middle Ordovician back-arc basin in the southern Appalachian Blue Ridge: characteristics, extent, and tectonic significance

    USGS Publications Warehouse

    Tull, James; Holm-Denoma, Christopher S.; Barineau, Clinton I.

    2014-01-01

    Fault-dismembered segments of a distinctive, extensive, highly allochthonous, and tectonically significant Ordovician (ca. 480–460 Ma) basin, which contains suites of bimodal metavolcanic rocks, associated base metal deposits, and thick immature deep-water (turbiditic) metasediments, occur in parts of the southern Appalachian Talladega belt, eastern Blue Ridge, and Inner Piedmont of Alabama, Georgia, and North and South Carolina. The basin's predominantly metasedimentary strata display geochemical and isotopic evidence of a mixed provenance, including an adjacent active volcanic arc and a provenance of mica (clay)-rich sedimentary and felsic plutonic rocks consistent with Laurentian (Grenvillian) upper-crustal continental rocks and their passive-margin cover sequences. Geochemical characteristics of the subordinate intercalated bimodal metavolcanic rocks indicate formation in a suprasubduction environment, most likely a back-arc basin, whereas characteristics of metasedimentary units suggest deposition above Neoproterozoic rift and outer-margin lower Paleozoic slope and rise sediments within a marginal basin along Ordovician Laurentia's Iapetus margin. This tectonic setting indicates that southernmost Appalachian Ordovician orogenesis (Taconic orogeny) began as an extensional accretionary orogen along the outer margin of Laurentia, rather than in an exotic (non-Laurentian) arc collisional setting. B-type subduction polarity requires that the associated arc-trench system formed southeast of the palinspastic position of the back-arc basin. This scenario can explain several unique features of the southern Appalachian Taconic orogen, including: the palinspastic geographic ordering of key tectonic elements (i.e., back-arc, arc, etc.), and a lack of (1) an obducted arc sensu stricto on the Laurentian margin, (2) widespread Ordovician regional metamorphism, and (3) Taconic klippen to supply detritus to the Taconic foreland basin.

  6. Assessment of Appalachian basin oil and gas resources: Carboniferous Coal-bed Gas Total Petroleum System: Chapter G.1 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Milici, Robert C.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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.

  7. Information relevant to the U.S. Geological Survey assessment of the Middle Devonian Shale of the Appalachian Basin Province, 2011

    USGS Publications Warehouse

    ,

    2011-01-01

    The U.S. Geological Survey recently assessed the potential for natural gas resources in the Middle Devonian Marcellus Shale of the Appalachian Basin Province. The Marcellus Shale was assessed as a continuous gas accumulation using a methodology identical to that used in the assessment of shale and other continuous-type assessment units throughout the United States. This preliminary report provides some additional geologic information used in the Marcellus Shale assessment. The Appalachian Basin Province encompasses rocks of the Paleozoic passive margins, the foreland basins, and fold and thrust belts formed during several episodes in the Paleozoic. The Marcellus Shale is one of many marine shales deposited in the area that is now encompassed by the Appalachian Basin Province.

  8. Biostratigraphic utility of organic-walled phytoplankton, Upper Ordovician-Lower Silurian of Appalachian basin

    SciTech Connect

    Colbath, G.K.

    1986-05-01

    Upper Ordovician-Lower Silurian marine mudstones in the Appalachian basin, which have not been subjected to extensive heating or oxidation, contain abundant organic-walled phytoplankton (prasinophycean algal phycomata and acritarchs). In most areas graptolites and conodonts have not been recovered from these rocks, making the phytoplankton particularly important for biostratigraphic correlation. Recent advances have improved the precision with which these microfossils can be used. By tabulating relative abundance data carefully, an abrupt change in the composition of phytoplankton associations can be recognized at the Ordovician-Silurian boundary can be located with greater precision and confidence than is possible using the stratigraphic ranges of individual species. Many supposedly long-ranging species have relatively short stratigraphic ranges, and thus greater utility, as a result of detailed taxonomic studies. Therefore, type and comparative material are important considerations. Also, vesicle wall architecture and dehiscent structures are valuable taxonomic characters. Scanning electron microscopy examination has improved our understanding of small forms (less than 20 ..mu..m in diameter), and has thus increased the number of taxa available for use in biostratigraphy. Further study of samples from vertically extensive stratigraphic sections of established age should help workers refine the biostratigraphy of these microfossils.

  9. Thermal maturity of northern Appalachian Basin Devonian shales: Insights from sterane and terpane biomarkers

    USGS Publications Warehouse

    Hackley, Paul C.; Ryder, Robert T.; Trippi, Michael H.; Alimi, Hossein

    2013-01-01

    To better estimate thermal maturity of Devonian shales in the northern Appalachian Basin, eleven samples of Marcellus and Huron Shale were characterized via multiple analytical techniques. Vitrinite reflectance, Rock–Eval pyrolysis, gas chromatography (GC) of whole rock extracts, and GC–mass spectrometry (GCMS) of extract saturate fractions were evaluated on three transects that lie across previously documented regional thermal maturity isolines. Results from vitrinite reflectance suggest that most samples are immature with respect to hydrocarbon generation. However, bulk geochemical data and sterane and terpane biomarker ratios from GCMS suggest that almost all samples are in the oil window. This observation is consistent with the presence of thermogenic gas in the study area and higher vitrinite reflectance values recorded from overlying Pennsylvanian coals. These results suggest that vitrinite reflectance is a poor predictor of thermal maturity in early mature areas of Devonian shale, perhaps because reported measurements often include determinations of solid bitumen reflectance. Vitrinite reflectance interpretations in areas of early mature Devonian shale should be supplanted by evaluation of thermal maturity information from biomarker ratios and bulk geochemical data.

  10. Utilization of gyroscopic compass with borehole television camera in Devonian shale wells, Appalachian basin

    SciTech Connect

    Walbe, K.

    1988-08-01

    The color Borehole Television Camera has, in the three short years since its introduction in the Appalachian basin, become an extremely valuable tool in evaluating wells in Devonian shale. This has been due to the camera's ability to detect fracturing and small hydrocarbon entries that are below the resolution threshold of conventional geophysical logging. This potential of the camera has been greatly enhanced by the addition of a gyroscopic compass to the basic tool. This compass gives the added value of orientation to observed phenomena in both open and cased holes. In the open hole, the camera can be used to determine the orientation of fracturing. This feature is extremely important because fracture orientation can vary with depth, which may be the reason that some previously observed fractures make gas, whereas others within the same well bore do not. The productive fracture orientation can also be tied back to regional lineation studies. Within the open hole, the gyroscope can also be used to orient sidewall coring operations so that cores can, in addition to regular analyses, be evaluated for directional properties, such as permeability and direction of the source beds. Induced fractures, created by open-hole stress testing, can also be observed and their orientation determined.

  11. Petrophysics of low-permeability medina sandstone, northwestern Pennsylvania, Appalachian Basin

    USGS Publications Warehouse

    Castle, J.W.; Byrnes, A.P.

    1998-01-01

    Petrophysical core testing combined with geophysical log analysis of low-permeability, Lower Silurian sandstones of the Appalachian basin provides guidelines and equations for predicting gas producibility. Permeability values are predictable from the borehole logs by applying empirically derived equations based on correlation between in-situ porosity and in-situ effective gas permeability. An Archie-form equation provides reasonable accuracy of log-derived water saturations because of saturated brine salinities and low clay content in the sands. Although measured porosity and permeability average less than 6% and 0.1 mD, infrequent values as high as 18% and 1,048 mD occur. Values of effective gas permeability at irreducible water saturation (Swi) range from 60% to 99% of routine values for the highest permeability rocks to several orders of magnitude less for the lowest permeability rocks. Sandstones having porosity greater than 6% and effective gas permeability greater than 0.01 mD exhibit Swi less than 20%. With decreasing porosity, Swi sharply increases to values near 40% at 3 porosity%. Analysis of cumulative storage and flow capacity indicates zones with porosity greater than 6% generally contain over 90% of flow capacity and hold a major portion of storage capacity. For rocks with Swi < 20%, gas relative permeabilities exceed 45%. Gas relative permeability and hydrocarbon volume decrease rapidly with increasing Swi as porosity drops below 6%. At Swi above 40%, gas relative permeabilities are less than approximately 10%.

  12. Selenium Concentrations in Middle Pennsylvanian Coal-Bearing Strata in the Central Appalachian Basin

    USGS Publications Warehouse

    Neuzil, Sandra G.; Dulong, Frank T.; Cecil, C. Blaine; Fedorko, Nick; Renton, John J.; Bhumbla, D.K.

    2007-01-01

    Introduction This report provides the results of a reconnaissance-level investigation of selenium (Se) concentrations in Middle Pennsylvanian coal-bearing strata in the central Appalachian basin. Bryant and others (2002) reported enrichments of Se concentrations in streams draining areas disturbed by surface mining relative to Se concentrations in streams that drain undisturbed areas; the study was conducted without the benefit of data on Se concentrations in coal-bearing strata prior to anthropogenic disturbance. Thus, the present study was conducted to provide data on Se concentrations in coal-bearing strata prior to land disturbance. The principal objectives of this work are: 1) determine the stratigraphic and regional distribution of Se concentrations in coal-bearing strata, 2) provide reconnaissance-level information on relations, if any, between Se concentrations and lithology (rock-type), and 3) develop a cursory evaluation of the leachability of Se from disturbed strata. The results reported herein are derived from analyses of samples obtained from three widely-spaced cores that were collected from undisturbed rock within a region that has been subjected to extensive land disturbance principally by either coal mining or, to a lesser extent, highway construction. The focus was on low-organic-content lithologies, not coal, within the coal-bearing interval, as these lithologies most commonly make up the fill materials after coal mining or in road construction.

  13. Mining conditions and deposition in the Amburgy (Westphalian B) coal, Breathitt Group, central Appalachian basin

    SciTech Connect

    Greb, S.F.; Eble, C.F.; Hower, J.C.; Phillips, T.L.

    1996-09-01

    Carbonate concretions called clay balls are rare in the Central Appalachian Basin, but were found in the Amburgy coal overlain by the Kendrick Shale Member. In the study area, the Amburgy coal is 0.7 to 0.9 meters thick, moderate to high in sulfur content, moderate to high in ash yield, and mostly bright clarain, except at the top near the area of coal balls, where durain of limited extent occurs. The coal is co-dominated by lycopod and cordaites; tree spores, with subordinate Calamites. The local durain layer is dominated by Densosporites, produced by the shrubby lycopod Ompbalophloios. Coal balls were encountered where the durain is immediately overlain by a coquinoid hash of broken and whole marine fossils, along a trend of coal thinning. The coal balls contain permineralized cordaites, lycopods, calamites, and ferns. The Amburgy coal accumulated as a succession of planar mires. Local splits in the seam are common, indicating contemporaneous clastic influx. The abundance of Cordaites may indicate brackish mire waters related to a coastal position and initial eustatic rise of the marginal Kendrick seas. Near the end of the Amburgy mires, the high ash-Omphalopbloios association is interpreted as a local area that was being drowned by the Kendrick transgression. Ravinement within this local embayment, rapid inundation by marine waters, and concentration of carbonate-bearing waters within transgressive scours may have contributed to the formation of coal balls and pyritic concretions in the upper part of the coal bed.

  14. What Controls Methane in Potable Ground Water in the Appalachian Basin?

    NASA Astrophysics Data System (ADS)

    Siegel, D. I.; Smith, B.; Perry, A. E.; Bothun, R.

    2014-12-01

    We present the results of baseline (pre-drilling) sampling for methane in 13,040 potable ground water samples in Northeastern Pennsylvania and 8,004 samples from a "Western Area" (southwest Pennsylvania, eastern Ohio, and north-central West Virginia) that were collected on behalf of Chesapeake Energy Corporation as part of its monitoring program prior to drilling unconventional oil and gas wells in the Marcellus and Utica Formations, as well as the results of a year-long study on temporal variability of methane in ground water at 12 locations in NE Pennsylvania We found dissolved methane common in potable ground water in the Appalachian Basin. In NE Pennsylvania, measureable dissolved methane occurred in 24% of our samples with 3.4% naturally exceeding the PADEP methane notification level of 7 mg/L. In the western area, dissolved methane occurred naturally in 36% of groundwater sampled and in Ohio, 4.1% of samples exceeded the Ohio dissolved methane action level of 10 mg/L. More methane is associated with hydrogeochemical facies trending towards Na-Cl and Na-HCO3 type waters in valleys and along hill flanks. We found no relationship occurs between the concentration of methane and proximity to pre-existing gas wells. Concentrations of methane in domestic wells can naturally vary by factors, depending on pumping regime and time of year.

  15. Evidence and mechanisms for Appalachian Basin brine migration into shallow aquifers in NE Pennsylvania, USA

    NASA Astrophysics Data System (ADS)

    Llewellyn, Garth T.

    2014-08-01

    Multiple geographic information system (GIS) datasets, including joint orientations from nine bedrock outcrops, inferred faults, topographic lineaments, geophysical data (e.g. regional gravity, magnetic and stress field), 290 pre-gas-drilling groundwater samples (Cl-Br data) and Appalachian Basin brine (ABB) Cl-Br data, have been integrated to assess pre-gas-drilling salinization sources throughout Susquehanna County, Pennsylvania (USA), a focus area of Marcellus Shale gas development. ABB has migrated naturally and preferentially to shallow aquifers along an inferred normal fault and certain topographic lineaments generally trending NNE-SSW, sub-parallel with the maximum regional horizontal compressive stress field (orientated NE-SW). Gravity and magnetic data provide supporting evidence for the inferred faults and for structural control of the topographic lineaments with dominant ABB shallow groundwater signatures. Significant permeability at depth, imparted by the geologic structures and their orientation to the regional stress field, likely facilitates vertical migration of ABB fluids from depth. ABB is known to currently exist within Ordovician through Devonian stratigraphic units, but likely originates from Upper Silurian strata, suggesting significant migration through geologic time, both vertically and laterally. The natural presence of ABB-impacted shallow groundwater has important implications for differentiating gas-drilling-derived brine contamination, in addition to exposing potential vertical migration pathways for gas-drilling impacts.

  16. Three phases of cooling and unroofing in the Appalachian Basin, Pennsylvania: Implications for flexural control

    SciTech Connect

    Blackmer, G.C.; Gold, D.P. . Dept. of Geosciences); Omar, G.I. . Geology Dept.)

    1992-01-01

    Apatite fission-track ages of 111--184 Ma and mean lengths of 10.7--13.1 [mu]m with unimodal, negatively skewed length distributions indicate slow cooling of Ordovician through Permian rocks in an area extending from the Anthracite Basin to the western Appalachian Plateau. Cooling histories modeled from fission-track data show that cooling began immediately following the Alleghanian Orogeny at 250--240 Ma. Ordovician rocks in the Juniata Culmination began to cool slightly earlier at 265 Ma, probably reflecting synorogenic unroofing of this area during formation of the Valley and Ridge duplex. Unroofing histories were modeled from cooling histories using the one-dimensional heat flow equation. Cooling and unroofing histories can be divided into three periods. The initial period of relatively rapid cooling and unroofing extended from the end of the Alleghanian Orogeny into the Jurassic and represents post-orogenic unroofing due to flexural rebound as orogenic load was removed through erosion. Initial unroofing rates are higher in eater Pennsylvania than in the west, consistent with a flexural model. A period of little to no unroofing from the Jurassic into the Miocene began contemporaneously with the inception of drift at the Atlantic continental margin. As the new continental margin subsided, the remaining load dropped below sea level and was no longer subject to removal, resulting in the cessation of flexural rebound and suppression of unroofing in the foreland. The most rapid unroofing occurred from the Miocene to the present. The nature of this event is unknown; however, it is also observed in increased sedimentation rates in the middle Atlantic offshore basins.

  17. Autogenic gas (self sourced) from shales - an example from the Appalachian Basin

    SciTech Connect

    Milici, R.C. )

    1993-01-01

    Black gas shales of Devonian and Mississippian age occur over much of the Appalachian basin, extending from eastern Tennessee north- and northeastward into Ohio and New York. In general, these shales were deposited along the distal margin of the Acadian Catskill delta in response to episodes of tectonic subsidence and regional transgression during the Acadian orogeny. A major trend of high organic carbon content in the black shales extends along the western side of the Catskill delta, from southwestern Virginia to the southern shores of Lake Erie. The high content of organic detritus in these Devonian and Mississippian black-shale source beds is probably related to high organic productivity in combination with moderate sedimentation rates along the distal margins of the Catskill delta. In general, organic matter in the black shales is more marine and oil prone on the western side of the basin, away from the major sources of siliciclastic input, than it is to the east. Thermal maturity trends follow depositional strike and isopachs of the Catskill delta and, thus, are related to depth of burial. Fracture porosity within the black shale sequence appears to have been affected mostly by regional decollement within discrete stratigraphic units that were, perhaps, overpressured during deformation. Shale gas is produced from relatively large fields in southwestern Virginia, eastern Kentucky, southwestern West Virginia, and southernmost Ohio. To the north, the strata rich in organic matter are thermally immature, and fields along the southern shores of lake Erie in Ohio and Pennsylvania are only marginally productive. To the east in northwestern West Virginia, the organic content of the shales is diluted by increased amounts of siliciclastics; organic matter is not sufficient to sustain long-term gas production, and shale-gas wells are short lived. 79 refs., 11 figs., 1 tab.

  18. Assessment of the Appalachian Basin Geothermal Field: Combining Risk Factors to Inform Development of Low Temperature Projects

    NASA Astrophysics Data System (ADS)

    Smith, J. D.; Whealton, C.; Camp, E. R.; Horowitz, F.; Frone, Z. S.; Jordan, T. E.; Stedinger, J. R.

    2015-12-01

    Exploration methods for deep geothermal energy projects must primarily consider whether or not a location has favorable thermal resources. Even where the thermal field is favorable, other factors may impede project development and success. A combined analysis of these factors and their uncertainty is a strategy for moving geothermal energy proposals forward from the exploration phase at the scale of a basin to the scale of a project, and further to design of geothermal systems. For a Department of Energy Geothermal Play Fairway Analysis we assessed quality metrics, which we call risk factors, in the Appalachian Basin of New York, Pennsylvania, and West Virginia. These included 1) thermal field variability, 2) productivity of natural reservoirs from which to extract heat, 3) potential for induced seismicity, and 4) presence of thermal utilization centers. The thermal field was determined using a 1D heat flow model for 13,400 bottomhole temperatures (BHT) from oil and gas wells. Steps included the development of i) a set of corrections to BHT data and ii) depth models of conductivity stratigraphy at each borehole based on generalized stratigraphy that was verified for a select set of wells. Wells are control points in a spatial statistical analysis that resulted in maps of the predicted mean thermal field properties and of the standard error of the predicted mean. Seismic risk was analyzed by comparing earthquakes and stress orientations in the basin to gravity and magnetic potential field edges at depth. Major edges in the potential fields served as interpolation boundaries for the thermal maps (Figure 1). Natural reservoirs were identified from published studies, and productivity was determined based on the expected permeability and dimensions of each reservoir. Visualizing the natural reservoirs and population centers on a map of the thermal field communicates options for viable pilot sites and project designs (Figure 1). Furthermore, combining the four risk

  19. Deciphering the mid-Carboniferous eustatic event in the central Appalachian foreland basin, southern West Virginia, USA

    USGS Publications Warehouse

    Blake, B.M.; Beuthin, J.D.

    2008-01-01

    A prominent unconformity, present across shallow shelf areas of the Euramerican paleoequatorial basins, is used to demark the boundary between the Mississippian and Pennsylvanian subsystems. This unconformity, the mid-Carboniferous eustatic event, is generally attributed to a major glacio-eustatic sea-level fall. Although a Mississippian-Pennsylvanian unconformity is recognized throughout most of the Appalachian region, the record of the mid-Carboniferous eustatic event in the structurally deepest part of the basin has been controversial. Based on early reports that suggested the most complete Pennsylvanian section was present in southern West Virginia, various conceptual depositional models postulated continuous sedimentation between the youngest Mississippian Bluestone Formation and the oldest Penn-sylvanian Pocahontas Formation. In contrast, tabular-erosion models envisioned axial drainage systems that evolved in response to changing basin dynamics. These models predicted a Mississippian-Pennsylvanian unconformity. All these models suffered from a lack of biostratigraphic control. The presence of a sub-Pocahontas paleovalley, herein named the Lashmeet paleovalley, has been confirmed in southern West Virginia. The Lashmeet paleovalley was incised over 35 m into Bluestone strata and filled by lithic sands derived from the Appalachian orogen to the northeast and east. The polygenetic Green Valley paleosol complex marks the Bluestone-Pocahontas contact on associated interfluves. Together, these features indicate a substantial period of subaerial exposure and argue strongly in favor of a Mississippian-Pennsylvanian unconformity. Paleontologic data from the Bluestone Formation, including marine invertebrates and conodonts from the marine Bramwell Member and paleofloral data, support a late, but not latest, Arnsbergian age assignment. Marine fossils are not known from the Pocahontas Formation, but macrofloral and palynomorph taxa support a Langsettian age for most of

  20. Age of the Bedford Shale, Berea Sandstone, and Sunbury Shale in the Appalachian and Michigan basins, Pennsylvania, Ohio, and Michigan

    USGS Publications Warehouse

    De Witt, Wallace

    1970-01-01

    The suggestion by Sanford (1967, p. 994) that the Bedford Shale, Berea Sandstone, and Sunbury Shale of the Michigan basin are of Late Devonian age because these strata contain Hymenozonotriletes lepidophytus Kedo is invalid for these formations in the Appalachian basin, the area of their type localities. Endosporites lacunosus Winslow, a synonym of Hymenozonotriletes lepidophytus Kedo, occurs in upper Chautauqua (Upper Devonian) rocks through much of the Kinderhook (Lower Mississippian) strata in Ohio. The Sunbury Shale, the Sunbury Member of the Orangeville Shale in part of northern Ohio, contains a Siplionodella fauna which clearly demonstrates the Kinderhook age of the unit. The basal strata of the Bedford Shale contain Spathoffnathodus anteposlcornis which suggests a very Late Devonian or very Early Mississippian age for this part of the Bedford. Except for the basal fossil zone, most of the Bedford Shale and the younger Berea Sandstone overlie the Murrysville sand, which along the Allegheny Front in central Pennsylvania contains an Adiantites flora of Early Mississippian (Kinderhook) age. The presence of Adiantites in the Murrysville sand indicates that most of the Bedford Shale and all the Berea Sandstone are of Early Mississippian age. Lithostratigraphic evidence suggests that the Berea Sandstone of Ohio may be a temporal equivalent of the basal Beckville Member of the Pocono Formation of the Anthracite region of Pennsylvania. The clearly demonstrable Kinderhook age of the Sunbury, Berea, and most of the Bedford in the Appalachian basin strongly indicates a similar age for the same units in the Michigan basin.

  1. Appalachian basin oil and natural gas: stratigraphic framework, total petroleum systems, and estimated ultimate recovery: Chapter C.1 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ryder, Robert T.; Milici, Robert C.; Swezey, Christopher S.; Trippi, Michael H.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    The most recent U.S. Geological Survey (USGS) assessment of undiscovered oil and gas resources of the Appalachian basin was completed in 2002 (Milici and others, 2003). This assessment was based on the total petroleum system (TPS), a concept introduced by Magoon and Dow (1994) and developed during subsequent studies such as those by the U.S. Geological Survey World Energy Assessment Team (2000) and by Biteau and others (2003a,b). Each TPS is based on specific geologic elements that include source rocks, traps and seals, reservoir rocks, and the generation and migration of hydrocarbons. This chapter identifies the TPSs defined in the 2002 Appalachian basin oil and gas assessment and places them in the context of the stratigraphic framework associated with regional geologic cross sections D–D′ (Ryder and others, 2009, which was re-released in this volume, chap. E.4.1) and E–E′ (Ryder and others, 2008, which was re-released in this volume, chap. E.4.2). Furthermore, the chapter presents a recent estimate of the ultimate recoverable oil and natural gas in the basin.

  2. Bituminous coal production in the Appalachian basin: past, present, and future: Chapter D.3 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Milici, Robert C.; Polyak, Désirée E.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    This report on Appalachian basin coal production consists of four plates and associated graphs and tables that were used to construct the maps. Figure 1 shows the decade of greatest coal production by county. Figure 2 shows the amount of coal produced for each county (in thousands of short tons) during the year of greatest coal production. These data are sorted by decade. Figure 3 illustrates the cumulative coal production (in thousands of short tons) for each county since about the beginning of the 20th century. Figure 4 shows 2003 production by county in thousands of short tons.

  3. In search of a Silurian total petroleum system in the Appalachian basin of New York, Ohio, Pennsylvania, and West Virginia: Chapter G.11 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ryder, Robert T.; Swezey, Christopher S.; Trippi, Michael H.; Lentz, Erika E.; Avary, K. Lee; Harper, John A.; Kappel, William M.; Rea, Ronald G.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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).

  4. Evidence for Cambrian petroleum source rocks in the Rome trough of West Virginia and Kentucky, Appalachian basin: Chapter G.8 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ryder, Robert T.; Harris, David C.; Gerome, Paul; Hainsworth, Timothy J.; Burruss, Robert A.; Lillis, Paul G.; Jarvie, Daniel M.; Pawlewicz, Mark J.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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.

  5. Innovative Methodology for Detection of Fracture-Controlled Sweet Spots in the Northern Appalachian Basin

    SciTech Connect

    Robert Jacobi; John Fountain; Stuart Loewenstein; Edward DeRidder; Bruce Hart

    2007-03-31

    For two consecutive years, 2004 and 2005, the largest natural gas well (in terms of gas flow/day) drilled onshore USA targeted the Ordovician Trenton/Black River (T/BR) play in the Appalachian Basin of New York State (NYS). Yet, little data were available concerning the characteristics of the play, or how to recognize and track T/BR prospects across the region. Traditional exploration techniques for entry into a hot play were of limited use here, since existing deep well logs and public domain seismic were almost non-existent. To help mitigate this problem, this research project was conceived with two objectives: (1) to demonstrate that integrative traditional and innovative techniques could be used as a cost-effective reconnaissance exploration methodology in this, and other, areas where existing data in targeted fracture-play horizons are almost non-existent, and (2) determine critical characteristics of the T/BR fields. The research region between Seneca and Cayuga lakes (in the Finger Lakes of NYS) is on strike and east of the discovery fields, and the southern boundary of the field area is about 8 km north of more recently discovered T/BR fields. Phase I, completed in 2004, consisted of integrating detailed outcrop fracture analyses with detailed soil gas analyses, lineaments, stratigraphy, seismic reflection data, well log data, and aeromagnetics. In the Seneca Lake region, Landsat lineaments (EarthSat, 1997) were coincident with fracture intensification domains (FIDs) and minor faults observed in outcrop and inferred from stratigraphy. Soil gas anomalies corresponded to ENE-trending lineaments and FIDs. N- and ENE-trending lineaments were parallel to aeromagnetic anomalies, whereas E-trending lineaments crossed aeromagnetic trends. 2-D seismic reflection data confirmed that the E-trending lineaments and FIDs occur where shallow level Alleghanian salt-cored thrust-faulted anticlines occur. In contrast, the ENE-trending FIDs and lineaments occur where Iapetan

  6. Assessment of undiscovered oil and gas resources of the Devonian Marcellus Shale of the Appalachian Basin Province

    USGS Publications Warehouse

    Coleman, James L.; Milici, Robert C.; Cook, Troy A.; Charpentier, Ronald R.; Kirshbaum, Mark; Klett, Timothy R.; Pollastro, Richard M.; Schenk, Christopher J.

    2011-01-01

    Using a geology-based assessment methodology, the U.S. Geological Survey (USGS) estimated a mean undiscovered natural gas resource of 84,198 billion cubic feet and a mean undiscovered natural gas liquids resource of 3,379 million barrels in the Devonian Marcellus Shale within the Appalachian Basin Province. All this resource occurs in continuous accumulations. In 2011, the USGS completed an assessment of the undiscovered oil and gas potential of the Devonian Marcellus Shale within the Appalachian Basin Province of the eastern United States. The Appalachian Basin Province includes parts of Alabama, Georgia, Kentucky, Maryland, New York, Ohio, Pennsylvania, Tennessee, Virginia, and West Virginia. The assessment of the Marcellus Shale is based on the geologic elements of this formation's total petroleum system (TPS) as recognized in the characteristics of the TPS as a petroleum source rock (source rock richness, thermal maturation, petroleum generation, and migration) as well as a reservoir rock (stratigraphic position and content and petrophysical properties). Together, these components confirm the Marcellus Shale as a continuous petroleum accumulation. Using the geologic framework, the USGS defined one TPS and three assessment units (AUs) within this TPS and quantitatively estimated the undiscovered oil and gas resources within the three AUs. For the purposes of this assessment, the Marcellus Shale is considered to be that Middle Devonian interval that consists primarily of shale and lesser amounts of bentonite, limestone, and siltstone occurring between the underlying Middle Devonian Onondaga Limestone (or its stratigraphic equivalents, the Needmore Shale and Huntersville Chert) and the overlying Middle Devonian Mahantango Formation (or its stratigraphic equivalents, the upper Millboro Shale and middle Hamilton Group).

  7. Current perspectives on unconventional shale gas extraction in the Appalachian Basin.

    PubMed

    Lampe, David J; Stolz, John F

    2015-01-01

    The Appalachian Basin is home to three major shales, the Upper Devonian, Marcellus, and Utica. Together, they contain significant quantities of tight oil, gas, and mixed hydrocarbons. The Marcellus alone is estimated to contain upwards of 500 trillion cubic feet of natural gas. The extraction of these deposits is facilitated by a combination of horizontal drilling and slick water stimulation (e.g., hydraulic fracturing) or "fracking." The process of fracking requires large volumes of water, proppant, and chemicals as well as a large well pad (3-7 acres) and an extensive network of gathering and transmission pipelines. Drilling can generate about 1,000 tons of drill cuttings depending on the depth of the formation and the length of the horizontal bore. The flowback and produced waters that return to the surface during production are high in total dissolved solids (TDS, 60,000-350,000 mg L(-1)) and contain halides (e.g., chloride, bromide, fluoride), strontium, barium, and often naturally occurring radioactive materials (NORMs) as well as organics. The condensate tanks used to store these fluids can off gas a plethora of volatile organic compounds. The waste water, with its high TDS may be recycled, treated, or disposed of through deep well injection. Where allowed, open impoundments used for recycling are a source of air borne contamination as they are often aerated. The gas may be "dry" (mostly methane) or "wet," the latter containing a mixture of light hydrocarbons and liquids that need to be separated from the methane. Although the wells can produce significant quantities of natural gas, from 2-7 bcf, their initial decline rates are significant (50-75%) and may cease to be economic within a few years. This review presents an overview of unconventional gas extraction highlighting the environmental impacts and challenges.

  8. Current perspectives on unconventional shale gas extraction in the Appalachian Basin.

    PubMed

    Lampe, David J; Stolz, John F

    2015-01-01

    The Appalachian Basin is home to three major shales, the Upper Devonian, Marcellus, and Utica. Together, they contain significant quantities of tight oil, gas, and mixed hydrocarbons. The Marcellus alone is estimated to contain upwards of 500 trillion cubic feet of natural gas. The extraction of these deposits is facilitated by a combination of horizontal drilling and slick water stimulation (e.g., hydraulic fracturing) or "fracking." The process of fracking requires large volumes of water, proppant, and chemicals as well as a large well pad (3-7 acres) and an extensive network of gathering and transmission pipelines. Drilling can generate about 1,000 tons of drill cuttings depending on the depth of the formation and the length of the horizontal bore. The flowback and produced waters that return to the surface during production are high in total dissolved solids (TDS, 60,000-350,000 mg L(-1)) and contain halides (e.g., chloride, bromide, fluoride), strontium, barium, and often naturally occurring radioactive materials (NORMs) as well as organics. The condensate tanks used to store these fluids can off gas a plethora of volatile organic compounds. The waste water, with its high TDS may be recycled, treated, or disposed of through deep well injection. Where allowed, open impoundments used for recycling are a source of air borne contamination as they are often aerated. The gas may be "dry" (mostly methane) or "wet," the latter containing a mixture of light hydrocarbons and liquids that need to be separated from the methane. Although the wells can produce significant quantities of natural gas, from 2-7 bcf, their initial decline rates are significant (50-75%) and may cease to be economic within a few years. This review presents an overview of unconventional gas extraction highlighting the environmental impacts and challenges. PMID:25734820

  9. Geologic assessment of natural gas from coal seams in the Northern Appalachian Coal Basin. Topical report, September 1986-September 1987

    SciTech Connect

    Kelafant, J.R.; Wicks, D.E.; Kuuskraa, V.A.

    1988-03-01

    Based on a geologic assessment of the Northern Appalachian Coal Basin, natural gas in place is estimated at 61 trillion cubic feet (Tcf), contained in 352,000 billion tons of coal. Over one third of the gas in place is in the deep, areally extensive Kittanning group (24.0 Tcf), although the Freeport (15.5 Tcf), Brookville/Clarion (11.0 Tcf), and Pittsburgh (7.0 Tcf) groups also hold considerable potential for coalbed gas. Five regional cross sections correlating the six major coal groups are included along with areal extent, overburden (depth of burial), coal isopach, and coal-rank maps.

  10. Study of the United States coal resources. [Appalachian Plateau, Interior Basins, Gulf Coastal Plain, Rocky Mountain Basins, High Plains, North Alaska

    SciTech Connect

    Ferm, J.C.; Muthig, P.J.

    1982-09-15

    The objectives of this study were: (1) the identification of geologically significant coal resources for the United States, including Alaska; and (2) the preparation of statistically controlled tonnage estimates for each resource type. Particular emphasis was placed on the identification and description of coals in terms of seam thickness, inclination, depth of cover, discontinuities caused by faulting and igneous intrusion, and occurrence as isolated or multiseam deposits. The national resource was organized into six major coal provinces: the Appalachian Plateau, the Interior Basins, the Gulf Coastal Plain, the Rocky Mountain Basins, the High Plains, and North Alaska. Total coal tonnage for a subarea was estimated from an analysis of the cumulative coal thickness derived from borehole or surface section records and subsequently categorized in terms of seam thickness, dip, overburden, multiseam proportions, coal quality, and tonnage impacted by severe faulting and igneous intrusions. Results indicate an aggregate resource in place of 11.6 trillion tons, of which North Alaska accounts for 3.5 trillion tons of subbituminous and bituminous coal; the Rocky Mountains, 2.2 trillion tons of bituminous and subbituminous deposits; and the Gulf Coast, 3.8 trillion tons of lignites. The Appalachian Plateau and Interior Basins are estimated to contain slightly less than 1 trillion tons each of bituminous coal, and the High Plains slightly more than 0.5 trillion tons of lignite. The Appalachian Plateau and Interior Basins are estimated to contain slightly less than 1 trillion tons each, and the High Plains Province is estimated to contain a bit more than 0.5 trillion tons. The implications of the results for research on advanced mining systems are discussed. 27 figures, 25 tables.

  11. Eustatic and tectonic control of deposition of the lower and middle Pennsylvanian strata of the Central Appalachian Basin

    USGS Publications Warehouse

    Chesnut, D.R.

    1997-01-01

    Stratigraphic analysis of Lower and Middle Pennsylvanian rocks of part of the Central Appalachian Basin reveals two orders of cycles and one overall trend in the vertical sequence of coal-bearing rocks. The smallest order cycle, the coal-clastic cycle, begins at the top of a major-resource coal bed and is composed of a vertical sequence of shale, siltstone, sandstone, seat rock, and overlying coal, which, in turn, is overlain by the next coal-clastic sequence. The average duration of the coal-clastic cycle has been calculated to be about 0.4 m.y. The major marine-transgression cycle is composed of five to seven coal-clastic cycles and is distinguished by the occurrence of widespread, relatively thick (generally thicker than 5 m) marine strata at its base. The duration of this cycle has been calculated to be about 2.5 m.y. The Breathitt coarsening-upward trend describes the general upward coarsening of the Middle Pennsylvanian part of the Breathitt Group. The Breathitt Group includes eight major marine-transgression cycles, and was deposited during a period of approximately 20 m.y. The average duration of coal-clastic cycles is of the same order of magnitude (105 year) as the Milankovitch orbital-eccentricity cycles, and matches the 0.4 m.y. second-order eccentricity cycle (Long Earth-Eccentricity cycle). These orbital periodicities are thought to modulate glacial stages and glacio-eustatic levels. The calculated periodicities of the coal-clastic cycles can be used as evidence for glacio-eustatic control of the coal-bearing rocks of the Appalachian Basin. The 2.5-m.y. periodicity of the major marine-transgression cycle does not match any known orbital or tectonic cycle; the cause of this cycle is unknown, but it might represent episodic thrusting in the orogen, propagation of intraplate stresses, or an unidentified orbital cycle. The Breathitt coarsening-upward trend is interpreted to represent the increasing intensity and proximity of the Alleghenian Orogeny

  12. Exploration potential of offshore northern California basins

    SciTech Connect

    Bachman, S.B.; Crouch, J.K.

    1988-01-01

    A series of exploratory wells was drilled in the northern California offshore basins in the 1960s following leasing of federal tracts off northern California, Oregon, and Washington. The drilling, although encountering numerous oil shows, was considered at the time to indicate low prospectivity in an area that extended as far south as the offshore Santa Maria basin. However, subsequent major discoveries in this decade in the offshore Santa Maria basin, such as the Point Arguello field, indicate that these offshore basins may be highly prospective exploration targets. Many of the key features of Monterey production in central and southern California are also present in the offshore basins of northern California. A new 5-year leasing plan has scheduled leasing in the northern California OCS starting in early 1989. The first basins on the schedule, the Point Arena and Eel River basins, differ in some respects. The Point Arena basin is more typical of a Monterey basin, with the potential for fractured chert reservoirs and organic-rich sections, deep burial of basinal sections to enhance the generation of higher gravity oils, and complex folding and faulting. The Eel River basin is more clastic-rich in its gas-producing, onshore extension. Key questions in the Eel River basin include whether the offshore, more distal stratigraphy will include Monterey-like biogenic sediments, and whether the basin has oil potential in addition to its proven gas potential. The Outer Santa Cruz basin shares a similar stratigraphy, structure, and hydrocarbon potential with the Point Arena basin. The Santa Cruz-Bodega basin, also with a similar stratigraphy, may have less exploration potential because erosion has thinned the Monterey section in parts of the basin.

  13. Multi-offset vertical seismic profiles: fracture and fault identification for Appalachian basin reservoirs - two case examples

    SciTech Connect

    Wyatt, D.E.; Bennett, B.A.; Walsh, J.J.

    1988-08-01

    Many Appalachian basin reservoirs occur in older rocks that are commonly fractured and faulted. These fractures and faults very often act as the reservoir trapping mechanism, especially in lithologies with no log-detectable matrix porosity. Traditional logging techniques, although possibly showing fault or fracture presence in the well bore, seldom provide clues to the extent of fracturing or location of nearby faults. Surface seismic data should show faults and perhaps even fracturing, but showing these features is often not possible in rugged terrain or in areas with thick coverings of unconsolidated surface material. Traditional seismic also has resolutions lower than that needed to detect small faults (less than 70 ft). Two case examples are shown from the northern Appalachian basin. The first example utilizes Schlumberger's slim hole seismic tool in cased holes in an area of thick unconsolidated glacial material along the Bass Island trend of western New York. The second example utilizes Schlumberger's SAT tool in an open-hole environment in an area of northwestern Pennsylvania with disturbed surface bedding and poor conventional surface seismic returns. The slim hole tool provides good data but with only slightly greater resolution than surface Vibroseis data. The SAT tool provides excellent resolution (down to 25 ft) in highly disturbed bedding.

  14. Assessment of Appalachian basin oil and gas resources:Devonian shale - Middle and Upper Paleozoic Total Petroleum System

    USGS Publications Warehouse

    Milici, Robert C.; Swezey, Christopher S.

    2006-01-01

    The U.S. Geological Survey (USGS) recently completed an assessment of the technically recoverable undiscovered hydrocarbon resources of the Appalachian Basin Province. The assessment province includes parts of New York, Pennsylvania, Ohio, Maryland, West Virginia, Virginia, Kentucky, Tennessee, Georgia and Alabama. The assessment was based on six major petroleum systems, which include strata that range in age from Cambrian to Pennsylvanian. The Devonian Shale-Middle and Upper Paleozoic Total Petroleum System (TPS) extends generally from New York to Tennessee. This petroleum system has produced a large proportion of the oil and natural gas that has been discovered in the Appalachian basin since the drilling of the Drake well in Pennsylvania in 1859. For assessment purposes, the TPS was divided into 10 assessment units (plays), 4 of which were classified as conventional and 6 as continuous. The results were reported as fully risked fractiles (F95, F50, F5 and the Mean), with the fractiles indicating the probability of recovery of the assessment amount. Products reported were oil (millions of barrels of oil, MMBO), gas (billions of cubic feet of gas, BCFG), and natural gas liquids (millions of barrels of natural gas liquids, MMBNGL). The mean estimates for technically recoverable undiscovered hydrocarbons in the TPS are: 7.53 MMBO, 31,418.88 BCFG (31.42 trillion cubic feet) of gas, and 562.07 MMBNGL.

  15. In search of a Silurian Total Petroleum System in the Appalachian Basin of New York, Ohio, Pennsylvania, and West Virginia

    USGS Publications Warehouse

    Ryder, Robert T.; Swezey, Christopher S.; Trippi, Michael H.; Lentz, Erika E.; Avary, K. Lee; Harper, John A.; Kappel, William M.; Rea, Ronald G.

    2007-01-01

    This report provides an evaluation of the source rock potential of Silurian strata in the U.S. portion of the northern Appalachian Basin, using new TOC and RockEval data. The study area consists of all or parts of New York, Ohio, Pennsylvania, and West Virginia. The stratigraphic intervals that were sampled for this study are as follows: 1) the Lower Silurian Cabot Head Shale, Rochester Shale, and Rose Hill Formation; 2) the Lower and Upper Silurian McKenzie Limestone, Lockport Dolomite, and Eramosa Member of the Lockport Group; and 3) the Upper Silurian Wills Creek Formation, Tonoloway Limestone, Salina Group, and Bass Islands Dolomite. These Silurian stratigraphic intervals were chosen because they are cited in previous publications as potential source rocks, they are easily identified and relatively continuous across the basin, and they contain beds of dark gray to black shale and (or) black argillaceous limestone and dolomite.

  16. Two basins explored in Dominican Republic

    SciTech Connect

    Ellis, G.M.

    1996-04-29

    Exploration companies are exploring two tracts in separate basins of the Dominican Republic. Drilling is under way or planned in the eastern Cibao basin in the northeastern part of the country, where Petrolera Once Once SA holds a 1,001,287 ha concession, and the Azua-Bani basin in the southwester, where Mobil-Murfin holds a 2,266,197 ha concession. About 75 wells have been drilled onshore in Dominican Republic, but commercial production has not been established. This paper summarizes the exploration history and geology of the area.

  17. China, JNOC start exploration in Tarim basin

    SciTech Connect

    Not Available

    1992-06-15

    This paper reports that a joint venture of China National Oil and Natural Gas Corp and Japan National Oil Corp (JNOC) has begun exploration in Northwest China's remote Tarim basin in Xinjiang Uygur Autonomous Region. That marks the first time China has allowed a foreign oil company to participate in exploration of the highly prospective basin. China pins much of its hope for the future on the Tarim basin as production declines from its older, mainstay fields in the east and offshore results have proved largely disappointing. The Chinese-Japanese combine began operations in the southwest part of the 560,000 sq km basin. The 200 member exploration team plans to complete a seismic survey covering 3,500 line km in the Kashi and Yecheng areas during the next 4 1/2 years. The survey follows a feasibility study that began last October covering 30,000 sq km in the basin.

  18. Innovative Methodology for Detection of Fracture-Controlled Sweet Spots in the Northern Appalachian Basin

    SciTech Connect

    Jacobi, Rober

    2007-03-31

    This Topical Report (#6 of 9) consists of the figures 3.6-13 to (and including) 3.6-18 (and appropriate figure captions) that accompany the Final Technical Progress Report entitled: "Fracture-Controlled Sweet Spots in the Northern Appalachian Basin” for DOE/NETL Award DE-AC26-00NT40698.

  19. Innovative Methodology For Detection of Fracture-Controlled Sweet Spots in the Northern Appalachian Basin

    SciTech Connect

    Jacobi, Rober

    2007-03-28

    This Topical Report (#6 of 9) consists of the figures 3.6-13 to (and including) 3.6-18 (and appropriate figure captions) that accompany the Final Technical Progress Report entitled: “Innovative Methodology for Detection of Fracture-Controlled Sweet Spots in the Northern Appalachian Basin” for DOE/NETL Award DE-AC26-00NT40698.

  20. Na-Cl-Br systematics of fluid inclusions from Mississippi Valley-type deposits, Appalachian Basin: Constraints on solute origin and migration paths

    SciTech Connect

    Kesler, S.E.; Martini, A.M.; Appold, M.S.; Walter, L.M.; Huston, T.J.; Furman, F.C.

    1996-01-01

    This study evaluated Na-Cl-Br systematics of fluid inclusion-hosted brines in Mississippi Valley-type (MVT) deposits from the Appalachian Basin. Unlike other geochemical tracers such as lead and strontium isotopes which constrain metal sources, Na-Cl-Br systematics identify sources of brine salinity. Saline formation waters can vary systematically within and between basins with regard to their Na-Cl-Br compositions depending on the importance of halite dissolution relative to retention of subaerially evaporated seawater for the halogen budget. Oil field brine compositions from the Illinois and Appalachian basins are quite distinct in their Na-Cl-Br systematics. Compositions of saline fluid inclusions in MVT deposits generally are consistent with these regional differences. These results shed new light on the extent of regional flow systems and on the geochemical evolution of saline fluids responsible for mineralization. Nearly all fluid inclusions analyzed from the Appalachian MVT deposits have Na/Br and Cl/Br ratios less than modern seawater, consistent with ratios observed in marine brines involved in halite precipitation. The Na-Cl-Br systematics of the brines responsible for Appalachian MVT deposits may be inherited from original marine brines refluxed into the porous carbonate shelf sediments that host these deposits. The Cl/Br and Na/Br ratios of most fluid inclusion-hosted brines from Appalachian MVT sphalerites and fluorites fall into two compositional groups, one from the Lower Cambrian paleoaquifer and another from the Lower Ordovician paleoaquifer. Leachates from most MVT barite deposits form a third compositional group having lower Na/Br and Cl/Br ratios than the other two. Appalachian MVT leachate compositions differ significantly from those in MVT deposits in the Cincinnati arch-midcontinent region suggesting that these two MVT provinces formed from brines of different origin or flow path. 59 refs., 8 figs., 2 tabs.

  1. The Areal Extent of Continuous Type Gas Accumulations in Lower Silurian Clinton Sands and Medina Group Sandstones of the Appalachian Basin and the Environments Affected by Their Development

    USGS Publications Warehouse

    Wandrey, C.J.; Ryder, Robert T.; Nuccio, Vito F.; Aggen, Kerry L.

    1997-01-01

    In order to best preserve and manage our energy and natural resources we must understand the relationships between these resources and the impacts of their development. To further this understanding the U.S. Geological Survey is studying unconventional continuous-type and, to a lesser extent, conventional oil and gas accumulations and the environmental impacts associated with their development. Continuous-type gas accumulations are generally characterized by low matrix permeabilities, large areal extents, and no distinct water contacts. This basin scale map shows the overall extent of these accumulations and the general land use types that may be impacted by their development. The Appalachian Basin has the longest history of oil and gas exploration and production in the United States. Since Drake's Titusville discovery well was drilled in 1859, oil and gas has been continuously produced in the basin. While there is still a great deal of oil and gas production, new field discoveries are rare and relatively small. For most of the second half of the 20th century the Appalachian basin has been considered a mature petroleum province because most of the large plays have already been discovered and developed. One exception to this trend is the Lower Silurian Clinton Sands and Medina Group Gas play which is being developed in New York, Pennsylvania, and Ohio. This continuous-type gas play has been expanding since the early 1970's (see inset maps). In the 1980's economic incentives such as large increases in wellhead prices further stimulated continuous-type gas resource development. Continuous-type gas plays can be large in areal extent and in thickness. 'Sweetspots' (areas of greater prodcution) are hard to predict and generally associated with better than average permeabilities, and enhanced by natural fracture systems. With an overall success rate often approaching 90%, drilling most of the play with closely spaced wells is often the best way to maximize gas recovery

  2. Thermal maturity patterns (conodont color alteration index and vitrinite reflectance) in Upper Ordovician and Devonian rocks of the Appalachian basin: a major revision of USGS Map I-917-E using new subsurface collections: Chapter F.1 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Repetski, John E.; Ryder, Robert T.; Weary, David J.; Harris, Anita G.; Trippi, Michael H.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    carbon (TOC) content in weight percent. Although the RockEval and TOC data are included in this chapter (table 1), they are not shown on the maps. The revised CAI isograd and percent vitrinite reflectance isograd maps cover all or parts of Kentucky, New York, Ohio, Pennsylvania, Virginia, and West Virginia (fig. 1), and the following three stratigraphic intervals: Upper Ordovician carbonate rocks, Lower and Middle Devonian carbonate rocks, and Middle and Upper Devonian black shales. These stratigraphic intervals were chosen for the following reasons: (1) they represent target reservoirs for much of the oil and gas exploration in the Appalachian basin; (2) they are stratigraphically near probable source rocks for most of the oil and gas; (3) they include geologic formations that are nearly continuous across the basin; (4) they contain abundant carbonate grainstone-packstone intervals, which give a reasonable to good probability of recovery of conodont elements from small samples of drill cuttings; and (5) the Middle and Upper Devonian black shale contains large amounts of organic matter for RockEval, TOC, and dispersed vitrinite analyses. Thermal maturity patterns of the Upper Ordovician Trenton Limestone are of particular interest here, because they closely approximate the thermal maturity patterns in the overlying Upper Ordovician Utica Shale, which is the probable source rock for oil and gas in the Upper Cambrian Rose Run Sandstone (sandstone), Upper Cambrian and Lower Ordovician Knox Group (Dolomite), Lower and Middle Ordovician Beekmantown Group (dolomite or Dolomite), Upper Ordovician Trenton and Black River Limestones, and Lower Silurian Clinton/Medina sandstone (Cole and others, 1987; Jenden and others, 1993; Laughrey and Baldassare, 1998; Ryder and others, 1998; Ryder and Zagorski, 2003). The thermal maturity patterns of the Lower Devonian Helderberg Limestone (Group), Middle Devonian Onondaga Limestone, and Middle Devonian Marcellus Shale-Upper Devonian Rhine

  3. Geologic Controls of Hydrocarbon Occurrence in the Southern Appalachian Basin in Eastern Tennessee, Southwestern Virginia, Eastern Kentucky, and Southern West Virginia

    SciTech Connect

    Robert D. Hatcher

    2003-05-31

    RDH for conodont alteration index determination to better define regional P-T conditions. Efforts are being made to calibrate and standardize geophysical log correlation, seismic reflection data, and Ordovician lithologic signatures to better resolve subsurface stratigraphy and structure beneath the poorly explored Plateau in Tennessee and southern Kentucky. We held a successful workshop on Ordovician rocks geophysical log correlation August 7, 2003 that was cosponsored by the Appalachian PTTC, the Kentucky and Tennessee geological surveys, the Tennessee Oil and Gas Association, and small independents. Detailed field structural and stratigraphic mapping of a transect across part of the Ordovician clastic wedge in Tennessee was begun in January 2003 to assist in 3-D reconstruction of part of the southern Appalachian basin and better assess the nature of a major potential source rock assemblage. (3) Laying the groundwork through (1) and (2) to understand reservoir architecture, the petroleum systems, ancient fluid migration, and conduct 3-D analysis of the southern Appalachian basin.

  4. Water resources and shale gas/oil production in the Appalachian Basin: critical issues and evolving developments

    USGS Publications Warehouse

    Kappel, William M.; Williams, John H.; Szabo, Zoltan

    2013-01-01

    Unconventional natural gas and oil resources in the United States are important components of a national energy program. While the Nation seeks greater energy independence and greener sources of energy, Federal agencies with environmental responsibilities, state and local regulators and water-resource agencies, and citizens throughout areas of unconventional shale gas development have concerns about the environmental effects of high volume hydraulic fracturing (HVHF), including those in the Appalachian Basin in the northeastern United States (fig. 1). Environmental concerns posing critical challenges include the availability and use of surface water and groundwater for hydraulic fracturing; the migration of stray gas and potential effects on overlying aquifers; the potential for flowback, formation fluids, and other wastes to contaminate surface water and groundwater; and the effects from drill pads, roads, and pipeline infrastructure on land disturbance in small watersheds and headwater streams (U.S. Government Printing Office, 2012). Federal, state, regional and local agencies, along with the gas industry, are striving to use the best science and technology to develop these unconventional resources in an environmentally safe manner. Some of these concerns were addressed in U.S. Geological Survey (USGS) Fact Sheet 2009–3032 (Soeder and Kappel, 2009) about potential critical effects on water resources associated with the development of gas extraction from the Marcellus Shale of the Hamilton Group (Ver Straeten and others, 1994). Since that time, (1) the extraction process has evolved, (2) environmental awareness related to high-volume hydraulic fracturing process has increased, (3) state regulations concerning gas well drilling have been modified, and (4) the practices used by industry to obtain, transport, recover, treat, recycle, and ultimately dispose of the spent fluids and solid waste materials have evolved. This report updates and expands on Fact Sheet 2009

  5. Utility of Isotopes to Understand the Effect of Shale Gas Drilling on Water Quality: Examples From the Appalachian Basin

    NASA Astrophysics Data System (ADS)

    Sharma, S.; Bowman, L.; Pelak, A.; Mulder, M.

    2014-12-01

    Marcellus Shale of the Appalachian Basin is one of the largest unconventional gas resources in the United States. The main public concern associated with hydraulic fracturing of Marcellus shale is that that the quality of underground sources of drinking water (USDW) and surface waters can be compromised due to well casing or grouting failures, creation of new fracture pathways, and improper disposal of produced water. However, this region has a long history of coal mining and oil /gas development and therefore it becomes very important to be able to distinguish if any incidence of water contamination is associated with legacy mining/drilling activities or the newly drilled shale gas wells. In addition, the complex structural regime of the Appalachian makes it difficult to decouple natural migration of deep brines and stray gas along geological faults/ fractures from new pathways created by hydraulic fracturing activities. In order to effectively assess the effect of shale gas development on water quality of this region there is a need 1) to establish the background geochemical signatures of different water sources and, 2) to develop geochemical fingerprints that can track the sources and fates of brines and stray gas in fresh waters. We will present results from several ongoing research projects which demonstrate applicability of stable isotopes as natural tracers to understand changes in hydrologic connections associated with shale gas drilling in this region.

  6. Ground-water quality in the Appalachian Plateaus, Kanawha River basin, West Virginia

    USGS Publications Warehouse

    Sheets, Charlynn J.; Kozar, Mark D.

    2000-01-01

    Water samples collected from 30 privately-owned and small public-supply wells in the Appalachian Plateaus of the Kanawha River Basin were analyzed for a wide range of constituents, including bacteria, major ions, nutrients, trace elements, radon, pesticides, and volatile organic compounds. Concentrations of most constituents from samples analyzed did not exceed U.S. Environmental Protection Agency (USEPA) standards. Constituents that exceeded drinking-water standards in at least one sample were total coliform bacteria, Escherichia coli (E. coli), iron, manganese, and sulfate. Total coliform bacteria were present in samples from five sites, and E. coli were present at only one site. USEPA secondary maximum contaminant levels (SMCLs) were exceeded for three constituents -- sulfate exceeded the SMCL of 250 mg/L (milligrams per liter) in samples from 2 of 30 wells; iron exceeded the SMCL of 300 ?g/L (micrograms per liter) in samples from 12 of the wells, and manganese exceeded the SMCL of 50 ?g/L in samples from 17 of the wells sampled. None of the samples contained concentrations of nutrients that exceeded the USEPA maximum contaminant levels (MCLs) for these constituents. The maximum concentration of nitrate detected was only 4.1 mg/L, which is below the MCL of 10 mg/L. Concentrations of nitrate in precipitation and shallow ground water are similar, potentially indicating that precipitation may be a source of nitrate in shallow ground water in the study area. Radon concentrations exceeded the recently proposed maximum contaminant level of 300 pCi/L at 50 percent of the sites sampled. The median concentration of radon was only 290 pCi/L. Radon-222 is a naturally occurring, carcinogenic, radioactive decay product of uranium. Concentrations, however, did not exceed the alternate maximum contaminant level (AMCL) for radon of 4,000 pCi/L in any of the 30 samples. Arsenic concentrations exceeded the proposed MCL of 5?g/L at 4 of the 30 sites. No samples exceeded the

  7. Assessment of undiscovered oil and gas resources of the Ordovician Utica Shale of the Appalachian Basin Province, 2012

    USGS Publications Warehouse

    Kirschbaum, Mark A.; Schenk, Christopher J.; Cook, Troy A.; Ryder, Robert T.; Charpentier, Ronald R.; Klett, Timothy R.; Gaswirth, Stephanie B.; Tennyson, Marilyn E.; Whidden, Katherine J.

    2012-01-01

    The U.S. Geological Survey assessed unconventional oil and gas resources of the Upper Ordovician Utica Shale and adjacent units in the Appalachian Basin Province. The assessment covers parts of Maryland, New York, Ohio, Pennsylvania, Virginia, and West Virginia. The geologic concept is that black shale of the Utica Shale and adjacent units generated hydrocarbons from Type II organic material in areas that are thermally mature for oil and gas. The source rocks generated petroleum that migrated into adjacent units, but also retained significant hydrocarbons within the matrix and adsorbed to organic matter of the shale. These are potentially technically recoverable resources that can be exploited by using horizontal drilling combined with hydraulic fracturing techniques.

  8. Black shale source rocks and oil generation in the Cambrian and Ordovician of the central Appalachian Basin, USA

    USGS Publications Warehouse

    Ryder, R.T.; Burruss, R.C.; Hatch, J.R.

    1998-01-01

    Nearly 600 million bbl of oil (MMBO) and 1 to 1.5 trillion ft3 (tcf) of gas have been produced from Cambrian and Ordovician reservoirs (carbonate and sandstone) in the Ohio part of the Appalachian basin and on adjoining arches in Ohio, Indiana, and Ontario, Canada. Most of the oil and gas is concentrated in the giant Lima-Indiana field on the Findlay and Kankakee arches and in small fields distributed along the Knox unconformity. Based on new geochemical analyses of oils, potential source rocks, bitumen extracts, and previously published geochemical data, we conclude that the oils in both groups of fields originated from Middle and Upper Ordovician blcak shale (Utica and Antes shales) in the Appalachian basin. Moroever, we suggest that approximately 300 MMBO and many trillions of cubic feet of gas in the Lower Silurian Clinton sands of eastern Ohio originated in the same source rocks. Oils from the Cambrian and Ordovician reservoirs have similar saturated hydrocarbon compositions, biomarker distributions, and carbon isotope signatures. Regional variations in the oils are attributed to differences in thermal maturation rather than to differences in source. Total organic carbon content, genetic potential, regional extent, and bitument extract geochemistry identify the balck shale of the Utica and Antes shales as the most plausible source of the oils. Other Cambrian and Ordovician shale and carbonate units, such as the Wells Creek formation, which rests on the Knox unconformity, and the Rome Formation and Conasauga Group in the Rome trough, are considered to be only local petroleum sources. Tmax, CAI, and pyrolysis yields from drill-hole cuttings and core indicate that the Utica Shale in eastern and central Ohio is mature with respect to oil generation. Burial, thermal, and hydrocarbon-generation history models suggest that much of the oil was generated from the Utica-Antes source in the late Paleozoic during the Alleghanian orogeny. A pervasive fracture network

  9. The northern and central Appalachian basin coal region -- The Upper Freeport and Pond Creek coal bed assessments

    SciTech Connect

    Ruppert, L.; Tewalt, S.; Bragg, L.; Wallack, R.; Freeman, P.; Tully, J.

    1999-07-01

    The Upper Freeport and Pond Creek coal beds are two of six coal beds being assessed by the US Geological Survey (USGS) in the northern and central Appalachian basin coal region. The coal resource assessments were designed to provide up-to-date, concise data on the location, quantity, and quality of US coals for Federal agencies, the public, industry and academia. Assessment products are fully digital and include original and remaining resource estimates; maps depicting areal extent, mined areas, geologic structure contour, isopach, overburden thickness, ash yield, sulfur content, calorific value, and selected trace-element contents; and public domain geochemical and stratigraphic databases. The assessment methodology and a few results are presented.

  10. Independent focuses Philippines exploration on Visayan basin

    SciTech Connect

    Rillera, F.G.

    1995-08-21

    Cophil Exploration Corp., a Filipino public company, spearheaded 1995 Philippine oil and gas exploration activity with the start of its gas delineation drilling operations in Libertad, northern Cebu. Cophil and its Australian partners, Coplex Resources NL and PacRim Energy NL, have set out to complete a seven well onshore drilling program within this block this year. The companies are testing two modest shallow gas plays, Libertad and Dalingding, and a small oil play, Maya, all in northern Cebu about 500 km southeast of Manila. Following a short discussion on the geology and exploration history of the Visayan basin, this article briefly summarizes Cophil`s ongoing Cebu onshore drilling program. Afterwards, discussion focuses on identified exploration opportunities in the basin`s offshore sector.

  11. Final report of special geological, geochemical, and petrological studies of the Devonian shales in the Appalachian Basin

    SciTech Connect

    Potter, P.E.; Maynard, J.B.; Pryor, W.A.

    1980-01-01

    The purpose of this study was to describe the geology, petrology, lithology, sedimentology, and stratigraphy of the Devonian Shales in the Appalachian Basin in order to determine the potential for gas recovery. Specific study areas include Pine Mountain Overthrust, Brallier Formation, and Ohio Shale along Lake Erie. discussion is presented under the main headings: Chemical Characterization;composition, Fabric, Texture, Bedding, and paleontology; and Basin Analysis. Paleocurrent studies indicate that the depositional strike of the basin in upper Devonian time was north-south with but little variation and that sediment was uniformly derived from the east. The total volume of shale sequence in the Pine Mountain Overthrust is 254 cubic miles. The blowout zone of Young (1957) was identified stratigraphically. The siltstones of the Brallier Formation are of rather low primary reservoir quality. Similar tight siltstones in the Benson Field of West Virginia show moderate gas production. Mudrock in Brallier outcrops do not show promise as source rock. Stratigraphic units along Lake Erir, which contain abundant mudshales, siltshales, and siltstones, make the best gas reservoirs. All of these shale types contain quartz laminae and/or quartzase siltstone and siltshale beds which act as permeable reservoirs and conduits for gas even though some are cemented by carbonate. (DMC)

  12. SECONDARY NATURAL GAS RECOVERY IN THE APPALACHIAN BASIN: APPLICATION OF ADVANCED TECHNOLOGIES IN A FIELD DEMONSTRATION SITE, HENDERSON DOME, WESTERN PENNSYLVANIA

    SciTech Connect

    BOB A. HARDAGE; ELOISE DOHERTY; STEPHEN E. LAUBACH; TUCKER F. HENTZ

    1998-08-14

    The principal objectives of this project were to test and evaluate technologies that would result in improved characterization of fractured natural-gas reservoirs in the Appalachian Basin. The Bureau of Economic Geology (Bureau) worked jointly with industry partner Atlas Resources, Inc. to design, execute, and evaluate several experimental tests toward this end. The experimental tests were of two types: (1) tests leading to a low-cost methodology whereby small-scale microfractures observed in matrix grains of sidewall cores can be used to deduce critical properties of large-scale fractures that control natural-gas production and (2) tests that verify methods whereby robust seismic shear (S) waves can be generated to detect and map fractured reservoir facies. The grain-scale microfracture approach to characterizing rock facies was developed in an ongoing Bureau research program that started before this Appalachian Basin study began. However, the method had not been tested in a wide variety of fracture systems, and the tectonic setting of rocks in the Appalachian Basin composed an ideal laboratory for perfecting the methodology. As a result of this Appalachian study, a low-cost commercial procedure now exists that will allow Appalachian operators to use scanning electron microscope (SEM) images of thin sections extracted from oriented sidewall cores to infer the spatial orientation, relative geologic timing, and population density of large-scale fracture systems in reservoir sandstones. These attributes are difficult to assess using conventional techniques. In the Henderson Dome area, large quartz-lined regional fractures having N20E strikes, and a subsidiary set of fractures having N70W strikes, are prevalent. An innovative method was also developed for obtaining the stratigraphic and geographic tops of sidewall cores. With currently deployed sidewall coring devices, no markings from which top orientation can be obtained are made on the sidewall core itself during

  13. Carboniferous sediment dispersal in the Appalachian-Ouachita juncture: Provenance of selected late Mississippian sandstones in the Black Warrior Basin, Mississippi, United States

    NASA Astrophysics Data System (ADS)

    Xie, Xiangyang; O'Connor, Patrick M.; Alsleben, Helge

    2016-08-01

    The Black Warrior Basin is one of several Carboniferous foreland basins along the Appalachian-Ouachita fold-thrust belt in the southeastern United States. Sediment dispersal within the Black Warrior Basin has been a long-debated topic because of a complex tectonic history and the potential interaction between the Appalachian and Ouachita orogenic belts, as well as far field sediment sources. Three dispersal patterns have been proposed, including dispersal routes from the craton, dispersal via the Appalachian foreland, and dispersal from the arc side of the Ouachita suture, but sediment dispersal in the Black Warrior Basin remains inconclusive. In this study, sandstone modal analysis and U-Pb detrital zircon geochronology are used to document the provenance and potential dispersal patterns for selected Mississippian sandstone units in the Black Warrior Basin, Missouri, USA. Results show that the majority of the Lewis, Evans, Sanders, and Carter sandstones are sublitharenite to mature quartzarenite and fall within the Cratonic Interior field on Q-F-L diagrams. U-Pb detrital zircon analyses of the Lewis, Sanders, and Carter sandstones show that there are four distinctive age clusters, including a prominent Paleozoic age cluster (~ 350-500 Ma), a broad Grenville age cluster (~ 900-1350 Ma), and two minor age clusters of the Granite-Rhyolite (~ 1360-1600 Ma) and the Yavapai-Mazatzal (~ 1600-1800 Ma) provinces. All Mississippian sandstones have similar age distributions except for the Lewis sandstone, which lacks zircon grains from the Superior province (>~2500 Ma). Based on the compositional maturity, similarity of age distributions, and changes of relative abundance among different age groups, we conclude that the Late Mississippian sandstone units analyzed during this study were derived from the Laurussian craton and the northern part of the Appalachian foreland through a major axial drainage that occupied the Mississippi Valley Graben.

  14. Choice of College Major: An Exploration of Appalachian Female Choice of an Early Childhood Education Major

    ERIC Educational Resources Information Center

    Gannoe, Lisa N.

    2013-01-01

    First generation Appalachian female students are exposed to gender differences in roles and career choices that are modeled in the family. A case study approach was used to obtain qualitative data from five students at Eastern Kentucky University and their mothers regarding why these students chose to major in child development and early childhood…

  15. Multi-scale and Integrated Characterization of the Marcellus Shale in the Appalachian Basin: From Microscopes to Mapping

    SciTech Connect

    Crandall, Dustin; Soeder, Daniel J; McDannell, Kalin T.; Mroz, Thomas

    2010-01-01

    Historic data from the Department of Energy Eastern Gas Shale Project (ESGP) were compiled to develop a database of geochemical analyses, well logs, lithological and natural fracture descriptions from oriented core, and reservoir parameters. The nine EGSP wells were located throughout the Appalachian Basin and intercepted the Marcellus Shale from depths of 750 meters (2500 ft) to 2500 meters (8200 ft). A primary goal of this research is to use these existing data to help construct a geologic framework model of the Marcellus Shale across the basin and link rock properties to gas productivity. In addition to the historic data, x-ray computerized tomography (CT) of entire cores with a voxel resolution of 240mm and optical microscopy to quantify mineral and organic volumes was performed. Porosity and permeability measurements in a high resolution, steady-state flow apparatus are also planned. Earth Vision software was utilized to display and perform volumetric calculations on individual wells, small areas with several horizontal wells, and on a regional basis. The results indicate that the lithologic character of the Marcellus Shale changes across the basin. Gas productivity appears to be influenced by the properties of the organic material and the mineral composition of the rock, local and regional structural features, the current state of in-situ stress, and lithologic controls on the geometry of induced fractures during stimulations. The recoverable gas volume from the Marcellus Shale is variable over the vertical stratigraphic section, as well as laterally across the basin. The results from this study are expected to help improve the assessment of the resource, and help optimize the recovery of natural gas.

  16. Multi-scale and Integrated Characterization of the Marcellus Shale in the Appalachian Basin: From Microscopes to Mapping

    NASA Astrophysics Data System (ADS)

    Soeder, D. J.; Mroz, T.; Crandall, D.; McDannell, K. T.

    2010-12-01

    Historic data from the DOE Eastern Gas Shale Project (EGSP) were compiled to develop a database of geochemical analyses, well logs, lithological and natural fracture descriptions from oriented core, and reservoir parameters. The EGSP wells were located throughout the Appalachian Basin. Nine wells intercept the Marcellus Shale from depths of 750 meters (2500 ft) to 2500 meters (8200 ft). The goals are to use these existing data to help construct a geologic framework model of the Marcellus Shale across the basin, and link rock properties to gas productivity. In addition to the historic data, several analytical tools were employed to determine kerogen distribution, natural and induced fracture morphology, and petrophysical properties of the formation, which is both a source and reservoir rock. The tools include x-ray computerized tomography (CT) of entire cores with a resolution of 0.24 mm, optical microscopy to quantify mineral and organic volume, acoustic microscopy to determine 3D spatial distribution of fractures and secondary minerals, and ion polished scanning electron microscopy to evaluate migration pathways for the fluids. Porosity and permeability measurements in a high resolution, steady-state flow apparatus are also planned. Earth Vision software was utilized to display and perform volumetric calculations on individual wells, small areas with several horizontal wells, and on a regional basis. The results indicate that lithologic character of the Marcellus Shale change across the basin. Gas productivity appears to be influenced by the properties of the organic material and the mineral composition of the rock, local and regional structural features, the current state of in-situ stress, and lithologic controls on the geometry of induced fractures during stimulations. The recoverable gas volume from the Marcellus Shale is variable over the vertical stratigraphic section, as well as laterally across the basin. The results from this study are expected to help

  17. Using 10Be to quantify rates of landscape change in 'dead' orogens - millennial scale rates of bedrock and basin-scale erosion in the southern and central Appalachian Mountains

    NASA Astrophysics Data System (ADS)

    Bierman, P. R.; Reusser, L.; Portenga, E.

    2011-12-01

    The Appalachian Mountain chain stretches north-south along the eastern margin of North America, in places rising a thousand meters and more above the adjacent piedmont. Here, Davis built his paradigm of landscape evolution, seeing landscape rejuvenation and dissected peneplains, a transient landscape. Hack saw the Appalachians as a dynamic system where topography was adjusted to rock strength, a steady-state landscape. Neither had quantitative data by which to test their theories. Today, we approach landscapes of the Appalachian Mountains quite differently. Over the past decade, we and others have measured in situ-produced 10Be in more than 300 samples of quartz isolated from Appalachian drainage basin sediments and in more than 100 samples from exposed Appalachian bedrock outcrops, most of which are on ridgelines. Samples have been collected from the Susquehanna, Potomac, and Shenandoah drainage basins as well as from the area around the Great Smoky Mountain National Park and the Blue Ridge escarpment, and from rivers draining from the Appalachians across the southeastern United States Piedmont. Most areas of the Appalachian Mountains are eroding only slowly; the average for all drainage basin samples analyzed to date is ~18 m/My (n=328). The highest basin-scale erosion rates, 25-70 m/My are found in the Appalachian Plateau and in the Great Smoky Mountains. Lower rates, on the order on 10-20 m/My, characterize the Shenandoah, Potomac, and Blue Ridge escarpment areas. There is a significant, positive relationship between basin-scale erosion rates and average basin slope. Steeper basins are in general eroding more rapidly than less steep basins. On the whole, the erosion rates of bedrock outcrops are either lower than or similar to those measured at a basin scale. The average erosion rate for samples of outcropping bedrock collected from the Appalachians is ~15 m/My (n=101). In the Potomac River Basin and the Great Smoky Mountains, bedrock and basin-scale erosion

  18. Stratigraphy of the Devonian Chattanooga and Ohio shales and equivalents in the Appalachian basin: an example of long-range subsurface correlation using gamma-ray logs

    SciTech Connect

    Roen, J.B.

    1980-01-01

    The correlations discussed demonstrate the utility of the gamma-ray log for regional, basinwide stratigraphic studies. Through the use of these logs, suggested correlations based on paleontologic evidence (Hass, 1956) were confirmed and new correlations were established in the Appalachian basin across at least 700 miles. These logs used in conjunction with a few lithologic logs and gamma-ray profiles of surface sections (Ettensohn and others, 1979) have proven to be a useful tool for long-range stratigraphic studies.

  19. Value of coenocorrelation curves in documenting sea level changes in Appalachian basin during Late Silurian and Early Devonian

    SciTech Connect

    Wong, S.

    1986-05-01

    A detailed paleoecological analysis of the Keyser Limestone was conducted at five localities in Virginia and West Virginia, using two multivariate statistical techniques: cluster analysis and detrended correspondence analysis. Through this analysis, the Keyser fauna was divided into communities along a nearshore to offshore environmental gradient, and each community was assigned to a benthic assemblage. Having established the proximity of the various faunal elements to the shoreline, the faunal zones at other localities, as described in the literature, were assigned to the appropriate benthic assemblage. Coenocorrelation curves were then constructed, based on benthic assemblage membership. By correlating the curves between each locality, the history of sea level changes in the Appalachian basin during the Late Silurian to Early Devonian were determined. Through this technique, more localities can be incorporated into detailed basin analysis studies. In this study, using coenocorrelation curves, it was found that the Keyser Limestone records several transgressive pulses. An initial transgressive pulse, affecting Virginia and West Virginia, resulted in the deposition of facies containing benthic assemblages 4 and 5. A second transgressive pulse resulted in the extension of these facies into Pennsylvania and New York. This transgressive pulse was followed by regressive conditions and the expansion of facies containing benthic assemblage 3. Subsequent transgression led to a return of facies containing benthic assemblages 4 and 5. Keyser deposition ended with a major regressive event, as recorded in the deposition of facies containing benthic assemblages 1-3.

  20. Facies analysis and depositional environment of the Ames Marine Member of the Conemaugh Group in the Appalachian Basin

    SciTech Connect

    Al-Qayim, B.A.

    1983-01-01

    The lithologic and paleontological aspects for fifty localities of the Ames Marine Member were examined. The regional stratigraphic reconstruction shows that it is variably composed of limestone and shale, and often associated with a thin basal coal seam. A generalized, composite stratigraphic section of the Ames Member consists of the following units from top to bottom: the Grafton Sandstone, Nonmarine Shale, Upper Ames Shale, Upper Ames Limestone, Middle Ames Shale, Lower Ames Limestone, Lower Ames Shale, Ames Coal, Nonmarine Silty Shale, and Harlem Coal. Harlem coal is commonly the basal coal in Ohio, and the Ames Coal is common in Pennsylvania and West Virginia. Insoluble residue analysis of 223 samples shows that quartz and glauconite are the major and significant residues. The major petrographic components of the Ames rocks are bioclastic grains of echinoderm, brachiopods, molluscs, bryozoa, and foraminifera in a matrix variably composed of clay and calcium carbonate. A quantitative microfacies study applying factor and cluster analysis reveals five basin-wide biofacies and four lithofacies reflecting a gradient from shoreline to an offshore position. The areal and vertical distribution of the different facies reflects the transgression-regression history of the Ames Cycle. A uniform slow eustatic rise of sea level with an early rapid transgression was responsible for the deposition of most of the Ames marine section. The small, upper, underdeveloped regressive section suggests a rapid regression by active prograding deltaic deposits which rapidly terminated the marine conditions over most the the Appalachian Basin.

  1. Factors controlling Li concentration and isotopic composition in formation waters and host rocks of Marcellus Shale, Appalachian Basin

    USGS Publications Warehouse

    Phan, Thai T.; Capo, Rosemary C; Stewart, Brian W.; Macpherson, Gwen; Rowan, Elisabeth L.; Hammack, Richard W.

    2015-01-01

    In Greene Co., southwest Pennsylvania, the Upper Devonian sandstone formation waters have δ7Li values of + 14.6 ± 1.2 (2SD, n = 25), and are distinct from Marcellus Shale formation waters which have δ7Li of + 10.0 ± 0.8 (2SD, n = 12). These two formation waters also maintain distinctive 87Sr/86Sr ratios suggesting hydrologic separation between these units. Applying temperature-dependent illitilization model to Marcellus Shale, we found that Li concentration in clay minerals increased with Li concentration in pore fluid during diagenetic illite-smectite transition. Samples from north central PA show a much smaller range in both δ7Li and 87Sr/86Sr than in southwest Pennsylvania. Spatial variations in Li and δ7Li values show that Marcellus formation waters are not homogeneous across the Appalachian Basin. Marcellus formation waters in the northeastern Pennsylvania portion of the basin show a much smaller range in both δ7Li and 87Sr/86Sr, suggesting long term, cross-formational fluid migration in this region. Assessing the impact of potential mixing of fresh water with deep formation water requires establishment of a geochemical and isotopic baseline in the shallow, fresh water aquifers, and site specific characterization of formation water, followed by long-term monitoring, particularly in regions of future shale gas development.

  2. ENHANCING RESERVOIR MANAGEMENT IN THE APPALACHIAN BASIN BY IDENTIFYING TECHNICAL BARRIER AND PREFERRED PRACTICES

    SciTech Connect

    Ronald R. McDowell; Khashayar Aminian; Katharine L. Avary; John M. Bocan; Michael Ed. Hohn; Douglas G. Patchen

    2003-09-01

    The Preferred Upstream Management Practices (PUMP) project, a two-year study sponsored by the United States Department of Energy (USDOE), had three primary objectives: (1) the identification of problems, problematic issues, potential solutions and preferred practices related to oil production; (2) the creation of an Appalachian Regional Council to oversee and continue this investigation beyond the end of the project; and (3) the dissemination of investigative results to the widest possible audience, primarily by means of an interactive website. Investigation and identification of oil production problems and preferred management practices began with a Problem Identification Workshop in January of 2002. Three general issues were selected by participants for discussion: Data Management; Reservoir Engineering; and Drilling Practices. At the same meeting, the concept of the creation of an oversight organization to evaluate and disseminated preferred management practices (PMP's) after the end of the project was put forth and volunteers were solicited. In-depth interviews were arranged with oil producers to gain more insight into problems and potential solutions. Project members encountered considerable reticence on the part of interviewees when it came to revealing company-specific production problems or company-specific solutions. This was the case even though interviewees were assured that all responses would be held in confidence. Nevertheless, the following production issues were identified and ranked in order of decreasing importance: Water production including brine disposal; Management of production and business data; Oil field power costs; Paraffin accumulation; Production practices including cementing. An number of secondary issues were also noted: Problems associated with Enhanced Oil Recovery (EOR) and Waterflooding; Reservoir characterization; Employee availability, training, and safety; and Sale and Purchase problems. One item was mentioned both in

  3. Paleoclimate controls on late paleozoic sedimentation and peat formation in the central appalachian basin (U.S.A.)

    USGS Publications Warehouse

    Cecil, C.B.; Stanton, R.W.; Neuzil, S.G.; Dulong, F.T.; Ruppert, L.F.; Pierce, B.S.

    1985-01-01

    In the central Appalachian basin, at least two major climate changes affected sedimentation during the late Paleozoic. Stratigraphically, these two changes are indicated by the distribution of coal beds, the variation in coal quality, and the variation in rock lithologies. In latest Mississippian or earliest Pennsylvanian time, the climate changed from dry-seasonal tropical to ever-wet (equable) tropical. The equable climate prevailed into the Middle Pennsylvanian, influencing the morphology and geochemistry in peat-forming environments. Many of the peat deposits, which formed under the equable climate, were probably domed (raised bogs); low concentrations of dissolved solids in peat formation water resulted in low buffering capacity. Organic acids caused acidic (pH < 4), antiseptic conditions that resulted in intense leaching of mineral matter, minimal degradation of organic matter, and low-ash and low-sulfur peat deposits; the resulting coal beds are also low in ash and sulfur. Associated rocks are noncalcareous and consist of sequences of interbedded shale, siltstone, and sandstone including quartz arenite. Another climate change occurred in late Middle Pennsylvanian time when evapopation periodically exceeded rainfall resulting in an increase of both dissolved solids and pH (4 to ??? 7) in surface and near-surface water. Throughout the remainder of the Pennsylvanian, the surfaces of peat deposits were probably planar (not domed); water in peat-forming and other depositional environments became more nearly neutral. The coal beds derived from these peats are highly variable in both ash and sulfur contents. Drier or more seasonal climates are also indicated by sequences of (1) calcareous sandstone and shale, (2) nonmarine limestone that shows shallow-water and subaerial exposure features, and (3) calcareous paleosols that have caliche characteristics. Our data and observations indicate that physical depositional environment models for the origin of coal do not

  4. Appalachian Basin Play Fairway Analysis: Thermal Quality Analysis in Low-Temperature Geothermal Play Fairway Analysis (GPFA-AB

    DOE Data Explorer

    Teresa E. Jordan

    2015-11-15

    This collection of files are part of a larger dataset uploaded in support of Low Temperature Geothermal Play Fairway Analysis for the Appalachian Basin (GPFA-AB, DOE Project DE-EE0006726). Phase 1 of the GPFA-AB project identified potential Geothermal Play Fairways within the Appalachian basin of Pennsylvania, West Virginia and New York. This was accomplished through analysis of 4 key criteria or ‘risks’: thermal quality, natural reservoir productivity, risk of seismicity, and heat utilization. Each of these analyses represent a distinct project task, with the fifth task encompassing combination of the 4 risks factors. Supporting data for all five tasks has been uploaded into the Geothermal Data Repository node of the National Geothermal Data System (NGDS). This submission comprises the data for Thermal Quality Analysis (project task 1) and includes all of the necessary shapefiles, rasters, datasets, code, and references to code repositories that were used to create the thermal resource and risk factor maps as part of the GPFA-AB project. The identified Geothermal Play Fairways are also provided with the larger dataset. Figures (.png) are provided as examples of the shapefiles and rasters. The regional standardized 1 square km grid used in the project is also provided as points (cell centers), polygons, and as a raster. Two ArcGIS toolboxes are available: 1) RegionalGridModels.tbx for creating resource and risk factor maps on the standardized grid, and 2) ThermalRiskFactorModels.tbx for use in making the thermal resource maps and cross sections. These toolboxes contain “item description” documentation for each model within the toolbox, and for the toolbox itself. This submission also contains three R scripts: 1) AddNewSeisFields.R to add seismic risk data to attribute tables of seismic risk, 2) StratifiedKrigingInterpolation.R for the interpolations used in the thermal resource analysis, and 3) LeaveOneOutCrossValidation.R for the cross validations used in

  5. A digital resource model of the Upper Pennsylvanian Pittsburgh coal bed, Monongahela Group, northern Appalachian basin coal region, USA

    USGS Publications Warehouse

    Ruppert, L.F.; Tewalt, S.J.; Bragg, L.J.; Wallack, R.N.

    1999-01-01

    The U.S. Geological Survey is currently conducting a coal resource assessment of the coal beds and zones that are expected to provide the bulk of the Nation's coal resources for the next few decades. The Pittsburgh coal bed is the first bed in the northern and central Appalachian basin coal region to undergo a fully-digital assessment. The bed-specific assessment is being carried out in partnership with the state geologic surveys of West Virginia (WV), Pennsylvania (PA), Ohio (OH), and Maryland (MD). Comprehensive stratigraphic and geochemical databases have been developed for the Pittsburgh coal bed, and areal extent, mined areas, structure contour, isopach, overburden thickness maps of the bed have been released as United States Geological Survey (USGS) Open-File Reports. The resulting resource model indicates that of the original 34 billion short tons (31 billion tonnes) of Pittsburgh coal, 16 billion short tons (14 billion tonnes) remain. Although most of the remaining coal is thinner, deeper, and higher in ash and sulfur (S) than the original resource, there are blocks of extensive thick (6-8 ft or 1.8-2.4 m) coal in southwestern PA and the northern panhandle of WV.The U.S. Geological Survey is currently conducting a coal resource assessment of the coal beds and zones that are expected to provide the bulk of the Nation's coal resources for the next few decades. The Pittsburgh coal bed is the first bed in the northern and central Appalachian basin coal region to undergo a fully-digital assessment. The bed-specific assessment is being carried out in partnership with the state geologic surveys of West Virginia (WV), Pennsylvania (PA), Ohio (OH), and Maryland (MD). Comprehensive stratigraphic and geochemical databases have been developed for the Pittsburgh coal bed, and areal extent, mined areas, structure contour, isopach, overburden thickness maps of the bed have been released as United States Geological Survey (USGS) Open-File Reports. The resulting resource

  6. Deep-water carbonate slope failure events in a newly discovered Silurian basin, Blue Ridge province, southern Appalachians, Tennessee

    SciTech Connect

    Unrug, R. )

    1991-03-01

    Siliciclastic deep-water turbidites of the Walden Creek Group, Ocoee Supergroup, underlying the foothills of the Great Smoky Mountains, contain olistolith blocks and olistostromal debris-flow breccia beds. Paleozoic fossils discovered recently in the olistoliths indicate Silurian age of the carbonates. The Walden Creek Group is therefore Silurian or younger, not late Proterozoic in age, as believed previously. The carbonate olistoliths and breccias formed by collapse of post-Taconic Silurian carbonate-dominated basin present in the Blue Ridge province of the Southern Appalachians into the younger basin of the Walden Creek Group. Two modes of occurrence of the olistoliths are present: (1) discrete horizons in which olistoliths are sitting spaced ten to hundreds of meters apart underneath a widespread conglomerate bed and (2) accumulations of olistoliths in localized stacked horizons in the vertical sequence of the enclosing siliciclastic rocks. Both modes can be related to failure of active fault scarps. Rocks of the olistolith are lithologically varied and record an older event of slope failure within the Silurian carbonate-dominated basin. Three facies assemblages representing two sedimentary environments are present in the olistoliths. Facies assemblage A includes oolitic limestone, stromatolite, carbonate breccia encrusted by stromatolite, and massive sandy limestone. It represents a high-energy, shallow-water, carbonate platform environment. Facies assemblage B consists of bedded dark limestone, alternating with black shale, and represents sediments of the carbonate platform slope. Facies assemblage C includes carbonate breccias intercalated in the bedded limestones and shales and is interpreted as deposits of the lower slope formed by failure of the carbonate platform margin.

  7. Improving the Availability and Delivery of Critical Information for Tight Gas Resource Development in the Appalachian Basin

    SciTech Connect

    Mary Behling; Susan Pool; Douglas Patchen; John Harper

    2008-12-31

    To encourage, facilitate and accelerate the development of tight gas reservoirs in the Appalachian basin, the geological surveys in Pennsylvania and West Virginia collected widely dispersed data on five gas plays and formatted these data into a large database that can be accessed by individual well or by play. The database and delivery system that were developed can be applied to any of the 30 gas plays that have been defined in the basin, but for this project, data compilation was restricted to the following: the Mississippian-Devonian Berea/Murrysville sandstone play and the Upper Devonian Venango, Bradford and Elk sandstone plays in Pennsylvania and West Virginia; and the 'Clinton'/Medina sandstone play in northwestern Pennsylvania. In addition, some data were collected on the Tuscarora Sandstone play in West Virginia, which is the lateral equivalent of the Medina Sandstone in Pennsylvania. Modern geophysical logs are the most common and cost-effective tools for evaluating reservoirs. Therefore, all of the well logs in the libraries of the two surveys from wells that had penetrated the key plays were scanned, generating nearly 75,000 scanned e-log files from more than 40,000 wells. A standard file-naming convention for scanned logs was developed, which includes the well API number, log curve type(s) scanned, and the availability of log analyses or half-scale logs. In addition to well logs, other types of documents were scanned, including core data (descriptions, analyses, porosity-permeability cross-plots), figures from relevant chapters of the Atlas of Major Appalachian Gas Plays, selected figures from survey publications, and information from unpublished reports and student theses and dissertations. Monthly and annual production data from 1979 to 2007 for West Virginia wells in these plays are available as well. The final database also includes digitized logs from more than 800 wells, sample descriptions from more than 550 wells, more than 600 digital photos

  8. Petroleum exploration in the Amadeus Basin

    NASA Astrophysics Data System (ADS)

    Roe, L. E.

    Although the spectacular outcrops in the Amadeus Basin have attracted researcher for many years, commercial exploration for oil started only in 1958. Up until 1973, 16 petroleum exploration wells were drilled and the major Mereenie Oil and Gas Field and the Palm Valley Gas Field were discovered. In both cases, the principal reservoir is the latest Cambrian-Early Ordovician Pacoota Sandstone; the reservoirs were sourced from the Early Ordovician Horn Valley Siltstone. Due to a combination of adverse circumstances, there was no exploration in the basin between 1973 and 1980. Since activity resumed, 14 further exploratory wells have been drilled and both the Mereenie and Palm Valley Fields have commenced production. The Dingo Gas Field, with flows form the basal part of the latest Proterozoic Arumbera Sandstone, was discovered in 1981. The Dingo Field is currently under study because of low flow rates from the reservoir. Exploration during the 1980's has brought out new concepts regarding the prospectiveness of parts of the basin, many of which have yet to be tested.

  9. Preliminary report on the clay mineralogy of the Upper Devonian Shales in the southern and middle Appalachian Basin

    USGS Publications Warehouse

    Hosterman, John W.; Loferski, Patricia J.

    1978-01-01

    The distribution of kaolinite in parts of the Devonian shale section is the most significant finding of this work. These shales are composed predominately of 2M illite and illitic mixed-layer clay with minor amounts of chlorite and kaolinite. Preliminary data indicate that kaolinite, the only allogenic clay mineral, is present in successively older beds of the Ohio Shale from south to north in the southern and middle parts of the Appalachian basin. This trend in the distribution of kaolinite shows a paleocurrent direction to the southwest. Three well-known methods of preparing the clay fraction for X-ray diffraction analysis were tested and evaluated. Kaolinite was not identified in two of the methods because of layering due to differing settling rates of the clay minerals. It is suggested that if one of the two settling methods of sample preparation is used, the clay film be thin enough for the X-ray beam to penetrate the entire thickness of clay.

  10. Geologic Cross Section D-D' Through the Appalachian Basin from the Findlay Arch, Sandusky County, Ohio, to the Valley and Ridge Province, Hardy County, West Virginia

    USGS Publications Warehouse

    Ryder, Robert T.; Crangle, Robert D.; Trippi, Michael H.; Swezey, Christopher S.; Lentz, Erika E.; Rowan, Elisabeth L.; Hope, Rebecca S.

    2009-01-01

    Geologic cross section D-D' is the second in a series of cross sections constructed by the U.S. Geological Survey to document and improve understanding of the geologic framework and petroleum systems of the Appalachian basin. Cross section D-D' provides a regional view of the structural and stratigraphic framework of the Appalachian basin from the Findlay arch in northwestern Ohio to the Valley and Ridge province in eastern West Virginia, a distance of approximately 290 miles. The information shown on the cross section is based on geological and geophysical data from 13 deep drill holes, several of which penetrate the Paleozoic sedimentary rocks of the basin and bottom in Mesoproterozoic (Grenville-age) crystalline basement rocks. This cross section is a companion to cross section E-E' (Ryder and others, 2008) that is located about 25 to 50 mi to the southwest. Although specific petroleum systems in the Appalachian basin are not identified on the cross section, many of their key elements (such as source rocks, reservoir rocks, seals, and traps) can be inferred from lithologic units, unconformities, and geologic structures shown on the cross section. Other aspects of petroleum systems (such as the timing of petroleum generation and preferred migration pathways) may be evaluated by burial history, thermal history, and fluid flow models based on information shown on the cross section. Cross section D-D' lacks the detail to illustrate key elements of coal systems (such as paleoclimate, coal quality, and coal rank), but it does provide a general geologic framework (stratigraphic units and general rock types) for the coal-bearing section. Also, cross section D-D' may be used as a reconnaissance tool to identify plausible geologic structures and strata for the subsurface storage of liquid waste or for the sequestration of carbon dioxide.

  11. Geologic Cross Section I–I′ Through the Appalachian Basin from the Eastern Margin of the Illinois Basin, Jefferson County, Kentucky, to the Valley and Ridge Province, Scott County, Virginia

    USGS Publications Warehouse

    Ryder, Robert T.; Trippi, Michael H.; Swezey, Christopher S.

    2015-12-08

    Cross section I‒I ’ contains much information that is useful for evaluating energy resources in the Appalachian basin. Many of the key elements of the Appalachian basin petroleum systems (such as source rocks, reservoir rocks, seals, and traps) can be inferred from lithologic units, unconformities, and geologic structures shown on the cross section. Other aspects of petroleum systems (such as the timing of petroleum generation and petroleum migration pathways) may be evaluated by burial history, thermal history, and fluid flow models on the basis of what is shown on the cross section. Cross section I‒I’ also provides a stratigraphic and structural framework for the Pennsylvanian coal-bearing section. In addition, geologists and engineers could use cross section I‒I’ as a reconnaissance tool to identify plausible geologic structures and strata for the subsurface storage of liquid waste or for the sequestration of carbon dioxide.

  12. Part I: Neoacadian to Alleghanian foreland basin development and provenance in the central appalachian orogen, pine mountain thrust sheet Part II: Structural configuration of a modified Mesozoic to Cenozoic forearc basin system, south-central Alaska

    NASA Astrophysics Data System (ADS)

    Robertson, Peter Benjamin

    Foreland and forearc basins are large sediment repositories that form in response to tectonic loading and lithospheric flexure during orogenesis along convergent plate boundaries. In addition to their numerous valuable natural resources, these systems preserve important geologic information regarding the timing and intensity of deformation, uplift and erosion history, and subsidence history along collisional margins, and, in ancient systems, may provide more macroscopic information regarding climate, plate motion, and eustatic sea level fluctuations. This thesis presents two studies focused in the Paleozoic Appalachian foreland basin system along the eastern United States and in the Mesozoic to Cenozoic Matanuska forearc basin system in south-central Alaska. Strata of the Appalachian foreland basin system preserve the dynamic history of orogenesis and sediment dispersal along the east Laurentian margin, recording multiple episodes of deformation and basin development during Paleozoic time. A well-exposed, >600 m thick measured stratigraphic section of the Pine Mountain thrust sheet at Pound Gap, Kentucky affords one of the most complete exposures of Upper Devonian through Middle Pennsylvanian strata in the basin. These strata provide a window into which the foreland basin's development during two major collisional events known as the Acadian-Neoacadian and the Alleghanian orogenies can be observed. Lithofacies analysis of four major sedimentary successions observed in hanging wall strata record the upward transition from (1) a submarine deltaic fan complex developed on a distal to proximal prodelta in Late Devonian to Middle Mississippian time, to (2) a Middle to Late Mississippian carbonate bank system developed on a slowly subsiding, distal foreland ramp, which was drowned by (3) Late Mississippian renewed clastic influx to a tidally influenced, coastal deltaic complex to fluvial delta plain system unconformably overlain by (4) a fluvial braided river complex

  13. Tourmaline in Appalachian - Caledonian massive sulphide deposits and its exploration significance.

    USGS Publications Warehouse

    Slack, J.F.

    1982-01-01

    Tourmaline is a common gangue mineral in several types of stratabound mineral deposits, including some massive base-metal sulphide ores of the Appalachian - Caledonian orogen. It is most abundant (sometimes forming massive foliated tourmalinite) in sediment-hosted deposits, such as those at the Elizabeth Cu mine and the Ore Knob Cu mine (North Carolina, USA). Trace amounts of tourmaline occur associated with volcanic-hosted deposits in the Piedmont and New England and also in the Trondheim district. Tourmaline associated with the massive sulphide deposits are Mg- rich dravites with major- and trace-element compositions significantly different from schorl. It is suggested that the necessary B was produced by submarine exhalative processes as a part of the same hydrothermal system that deposited the ores. An abundance of dravite in non-evaporitic terrains is believed to indicate proximity to former subaqueous fumarolic centres.-R.A.H.

  14. Palynology, geochemistry and Re-Os age of the Lower-Middle Pennsylvanian stage boundary, central Appalachian basin, USA

    NASA Astrophysics Data System (ADS)

    Geboy, N.; Tripathy, G. R.; Ruppert, L. F.; Eble, C. F.; Blake, B. M.; Hannah, J. L.; Stein, H. J.

    2014-12-01

    The central Appalachian basin (CAB) in the eastern United States contains complicated sedimentary sequences often with thin and discontinuous strata. As an economically important coal-producing region, the basin's architectural framework and depositional history are important to understand. Typically, eustatic marine incursions, marked with black shale deposits, are used for basin-wide correlation. The Betsie Shale Member of the Kanawha Formation represents one of these relatively thick and laterally extensive marine zones. This study examines the palynoflora of the Matewan coalbed, which conformably underlies the Betsie, in the context of a new Re-Os date for the Betsie Shale Member and additional geochemical measures. At its base, the Matewan contains abundant lycopsid tree spores, indicative of a submerged, flooded paleomire. Upsection, biodiversity increases to include small fern and calamite spores as well as cordaite pollen. Combined with an observed increase of inertinite, the diversification of palynoflora suggests surficial peat exposure and drying out of the paleomire. A S-rich (28 wt. %) shaley parting separates these lower and upper benches of the Matewan and may represent an initial marine pulse prior to the glacioeustatic incursion that ultimately flooded the Matewan and deposited the overlying Betsie Shale. The Betsie is organic-rich (3.05 - 4.89 wt. % TOC) with Re and Os content ranging from 320 - 1,200 ppb and 1.5 - 5.3 ppb, respectively. The highly enriched Re values result in notably high parent:daughter ratios (187Re/188Os = 3,644 - 5,737). The Re-Os isotopic data yield a Model 1 age of 323 ± 7.8 Ma (n = 7; MSWD = 0.63) with evidence that the true age lies closer to the younger end of the uncertainty. This age is consistent with previous paleontologic-based interpretations but represents the first directly measured radiometric date for the Betsie. An absolute age for the Betsie is a critical result, as the member is correlated with units in

  15. Petrophysics of Lower Silurian sandstones and integration with the tectonic-stratigraphic framework, Appalachian basin, United States

    USGS Publications Warehouse

    Castle, J.W.; Byrnes, A.P.

    2005-01-01

    Petrophysical properties were determined for six facies in Lower Silurian sandstones of the Appalachian basin: fluvial, estuarine, upper shoreface, lower shoreface, tidal channel, and tidal flat. Fluvial sandstones have the highest permeability for a given porosity and exhibit a wide range of porosity (2-18%) and permeability (0.002-450 md). With a transition-zone thickness of only 1-6 m (3-20 ft), fluvial sandstones with permeability greater than 5 md have irreducible water saturation (Siw) less than 20%, typical of many gas reservoirs. Upper shoreface sandstones exhibit good reservoir properties with high porosity (10-21%), high permeability (3-250 md), and low S iw (<20%). Lower shoreface sandstones, which are finer grained, have lower porosity (4-12%), lower permeability (0.0007-4 md), thicker transition zones (6-180 m [20-600 ft]), and higher S iw. In the tidal-channel, tidal-flat, and estuarine facies, low porosity (average < 6%), low permeability (average < 0.02 md), and small pore throats result in large transition zones (30-200 m; 100-650 ft) and high water saturations. The most favorable reservoir petrophysical properties and the best estimated production from the Lower Silurian sandstones are associated with fluvial and upper shoreface facies of incised-valley fills, which we interpret to have formed predominantly in areas of structural recesses that evolved from promontories along a collisional margin during the Taconic orogeny. Although the total thickness of the sandstone may not be as great in these areas, reservoir quality is better than in adjacent structural salients, which is attributed to higher energy depositional processes and shallower maximum burial depth in the recesses than in the salients. Copyright ??2005. The American Association of Petroleum Geologists. All rights reserved.

  16. Utilization Analysis in Low-Temperature Geothermal Play Fairway Analysis for the Appalachian Basin (GPFA-AB)

    DOE Data Explorer

    Teresa E. Jordan

    2015-09-30

    This submission of Utilization Analysis data to the Geothermal Data Repository (GDR) node of the National Geothermal Data System (NGDS) is in support of Phase 1 Low Temperature Geothermal Play Fairway Analysis for the Appalachian Basin (project DE-EE0006726). The submission includes data pertinent to the methods and results of an analysis of the Surface Levelized Cost of Heat (SLCOH) for US Census Bureau ‘Places’ within the study area. This was calculated using a modification of a program called GEOPHIRES, available at http://koenraadbeckers.net/geophires/index.php. The MATLAB modules used in conjunction with GEOPHIRES, the MATLAB data input file, the GEOPHIRES output data file, and an explanation of the software components have been provided. Results of the SLCOH analysis appear on 4 .png image files as mapped ‘risk’ of heat utilization. For each of the 4 image (.png) files, there is an accompanying georeferenced TIF (.tif) file by the same name. In addition to calculating SLCOH, this Task 4 also identified many sites that may be prospects for use of a geothermal district heating system, based on their size and industry, rather than on the SLCOH. An industry sorted listing of the sites (.xlsx) and a map of these sites plotted as a layer onto different iterations of maps combining the three geological risk factors (Thermal Quality, Natural Reservoir Quality, and Risk of Seismicity) has been provided. In addition to the 6 image (.png) files of the maps in this series, a shape (.shp) file and 7 associated files are included as well. Finally, supporting files (.pdf) describing the utilization analysis methodology and summarizing the anticipated permitting for a deep district heating system are supplied.

  17. Subsurface geometry and growth history of the Warfield Structure in South-Central West Virginia, Central Appalachian basin

    SciTech Connect

    Gao, D.; Shumaker, R.C. )

    1994-08-01

    The Warfield structure is located at the eastern margin of Rome trough in south-central West Virginia, an intersection area between the 38th parallel and the Burning Springs lineaments in the central Appalachian basin. Using SURFACE III and MCS contouring packages, structure maps of upper Paleozoic horizons were completed by retrieving, editing, and contouring over 6000 shallow wells from the database of the DEAM (Data Editing and Management) software package. The Warfield anticline is horizontal at the Mississippian horizons, with a generally northeast-trending closure and a northwest-dipping axial plane, but at the Devonian level the closure is lost as the fold plunges northeastward. Structures from the Oriskany horizon to the basement were interpolated based on seismic and well data with a multisurface STACK procedure of the MCS package, and demonstrate a constrained half graben underneath the Warfield anticline with a 38th parallel and the north-south-trending Burning Springs lineaments. Based on preliminary results from subsurface mapping, digitization, and quantitative analysis of seismic time sections as well as computer modeling for the magnetic/gravity anomalies, the authors postulate that the geometry and growth history of the Warfield structure were genetically controlled by a wedge-shaped basement fault system in which the strike-slip displacement along both the eastwest-trending and the north-south-trending faults, and the dip-slip displacement on the northeast-trending faults occurred synchronously in response to the episodic movement of a wedge-shaped basement block bounded by the east-west-trending 38th parallel and the north-south-trending Burning Springs lineaments as well as the northeast-trending trough-margin faults throughout the Paleozoic.

  18. Alabama's Appalachian overthrust amid exploratory drilling resurgence

    SciTech Connect

    Taylor, J.D. ); Epsman, M.L.

    1991-06-24

    Oil and gas exploration has been carried out sporadically in the Appalachian overthrust region of Alabama for years, but recently interest in the play has had a major resurgence. The Appalachian overthrust region of Alabama is best exposed in the valley and ridge physiographic province in the northeast part of the state. Resistant ridges of sandstone and chert and valleys of shales and carbonate have been thrust toward the northwest. Seismic data show that this structural style continues under the Cretaceous overlap. The surface and subsurface expression of the Alabama overthrust extends for more than 4,000 sq miles. Oil and gas have been produced for many years from Cambro-Ordovician, Ordovician, Mississippian, and Pennsylvanian rocks in the nearby Black Warrior basin in Alabama and Mississippi and the Cumberland plateau in Tennessee. The same zones are also potential producing horizons in the Alabama overthrust region.

  19. Black Appalachians.

    ERIC Educational Resources Information Center

    Waage, Fred, Ed.; Cabbell, Ed, Ed.

    1986-01-01

    This issue of "Now and Then" focuses on black Appalachians, their culture, and their history. It contains local histories, articles, and poems and short stories by Appalachian blacks. Articles include: "A Mountain Artist's Landscape," a profile of artist Rita Bradley by Pat Arnow; "A Part and Apart," a profile of black historian Ed Cabbell by Pat…

  20. Managing exploration risk using basin modeling

    SciTech Connect

    Wendebourg, J. )

    1996-01-01

    Economic risk analysis requires a well's dry-hole probability and a probability distribution of type and volume of recoverable hydrocarbons. Today's world-wide exploration needs methods that can accommodate a wide variety of data quality and quantity. Monte Carlo methods are commonly used to compute volume distributions and dry hole probability by multiplying Probabilities of geologic risk factors such as source rock richness, migration loss, seal effectiveness etc. assuming that these are independent Parameters. This assumption however is not appropriate because they represent interdependent physical processes that should be treated by an integrated system. Basin modeling is a tool for assessing exploration risk by simulating the interdependent processes that lead to hydrocarbon accumulations. advanced 2-D and 3-D basin modeling can treat occurrence, type, and volumes of hydrocarbons. These models need many parameters that individually may have great uncertainties, but a calibration against available data may reduce their uncertainties significantly and therefore may quantify risk. Uncertainty of thermal and source rock parameters is evaluated by applying simple and fast 1-D tools to individual wells. Calibration of pressure and temperature data as well as occurrence and type of known hydrocarbon accumulations with 2-D tools evaluates uncertainty between wells along geologic cross-sections. Individual prospect risk is finally determined by the uncertainty of local parameters within the calibrated model, as for example seal effectiveness or fault permeability.

  1. Managing exploration risk using basin modeling

    SciTech Connect

    Wendebourg, J.

    1996-12-31

    Economic risk analysis requires a well`s dry-hole probability and a probability distribution of type and volume of recoverable hydrocarbons. Today`s world-wide exploration needs methods that can accommodate a wide variety of data quality and quantity. Monte Carlo methods are commonly used to compute volume distributions and dry hole probability by multiplying Probabilities of geologic risk factors such as source rock richness, migration loss, seal effectiveness etc. assuming that these are independent Parameters. This assumption however is not appropriate because they represent interdependent physical processes that should be treated by an integrated system. Basin modeling is a tool for assessing exploration risk by simulating the interdependent processes that lead to hydrocarbon accumulations. advanced 2-D and 3-D basin modeling can treat occurrence, type, and volumes of hydrocarbons. These models need many parameters that individually may have great uncertainties, but a calibration against available data may reduce their uncertainties significantly and therefore may quantify risk. Uncertainty of thermal and source rock parameters is evaluated by applying simple and fast 1-D tools to individual wells. Calibration of pressure and temperature data as well as occurrence and type of known hydrocarbon accumulations with 2-D tools evaluates uncertainty between wells along geologic cross-sections. Individual prospect risk is finally determined by the uncertainty of local parameters within the calibrated model, as for example seal effectiveness or fault permeability.

  2. Paleoecological interpretation of a middle Pennsylvanian coal bed in the central Appalachian basin, U.S.A.

    USGS Publications Warehouse

    Eble, C.F.; Grady, W.C.

    1990-01-01

    change in palynflora and by the establishment and proliferation of some plant groups, notably cordaites and calamites, that may have been better adapted to growth on mineral soils. These palynologic and petrographic relationships, thought to be indicative of a domed peat-swamp origin, are not confined to the Hernshaw-Fire Clay coal bed, but appear to be characteristic of many coal beds in the Appalachian basin, and also of coal beds in other basins. ?? 1990.

  3. Thermal Maturity Patterns (CAI and %Ro) in Upper Ordovician and Devonian Rocks of the Appalachian Basin: A Major Revision of USGS Map I-917-E Using New Subsurface Collections

    USGS Publications Warehouse

    Repetski, John E.; Ryder, Robert T.; Weary, David J.; Harris, Anita G.; Trippi, Michael H.

    2008-01-01

    The conodont color alteration index (CAI) introduced by Epstein and others (1977) and Harris and others (1978) is an important criterion for estimating the thermal maturity of Ordovician to Mississippian rocks in the Appalachian basin. Consequently, the CAI isograd maps of Harris and others (1978) are commonly used by geologists to characterize the thermal and burial history of the Appalachian basin and to better understand the origin and distribution of oil and gas resources in the basin. The main objectives of our report are to present new CAI isograd maps for Ordovician and Devonian rocks in the Appalachian basin and to interpret the geologic and petroleum resource implications of these maps. The CAI isograd maps presented herein complement, and in some areas replace, the CAI-based isograd maps of Harris and others (1978) for the Appalachian basin. The CAI data presented in this report were derived almost entirely from subsurface samples, whereas the CAI data used by Harris and others (1978) were derived almost entirely from outcrop samples. Because of the different sampling methods, there is little geographic overlap of the two data sets. The new data set is mostly from the Allegheny Plateau structural province and most of the data set of Harris and others (1978) is from the Valley and Ridge structural province, east of the Allegheny structural front.

  4. Perspective of gas exploration in Ying-Qiong Basin

    SciTech Connect

    He, Hanyi; Zhongtiang Hu )

    1996-01-01

    The Yinggehai and Qiongdongnan Basin (Ying-Qiong Basin) in the northwest part of the South China Sea is a Cenozoic sedimentary basin, which has fast-subsiding and thick sediments. The maximum Cenozoic sediments in the center part of the basin is 20,000 m. Six sets of source rocks with prevailing Type III kerogen were developed in the basin, which has a great potential for gas generation. Different types of reservoirs and traps, leading to different assemblages of source rocks, reservoirs, and cap rocks, form good gas pools. Abnormal high temperature and high pressure in the basin resulted in many mud diapirs and made the generation, migration, and accumulation of gas more colorful. Up to now, four gas fields have been discovered in the basin. A large number of anticlines and stratigraphic-lithologic traps in the basin provide an extensive area for gas exploration. The perspective of gas exploration in the basin is vast and bright.

  5. Perspective of gas exploration in Ying-Qiong Basin

    SciTech Connect

    He, Hanyi; Zhongtiang Hu

    1996-12-31

    The Yinggehai and Qiongdongnan Basin (Ying-Qiong Basin) in the northwest part of the South China Sea is a Cenozoic sedimentary basin, which has fast-subsiding and thick sediments. The maximum Cenozoic sediments in the center part of the basin is 20,000 m. Six sets of source rocks with prevailing Type III kerogen were developed in the basin, which has a great potential for gas generation. Different types of reservoirs and traps, leading to different assemblages of source rocks, reservoirs, and cap rocks, form good gas pools. Abnormal high temperature and high pressure in the basin resulted in many mud diapirs and made the generation, migration, and accumulation of gas more colorful. Up to now, four gas fields have been discovered in the basin. A large number of anticlines and stratigraphic-lithologic traps in the basin provide an extensive area for gas exploration. The perspective of gas exploration in the basin is vast and bright.

  6. Geologic Cross Section E-E' through the Appalachian Basin from the Findlay Arch, Wood County, Ohio, to the Valley and Ridge Province, Pendleton County, West Virginia

    USGS Publications Warehouse

    Ryder, Robert T.; Swezey, Christopher S.; Crangle, Robert D.; Trippi, Michael H.

    2008-01-01

    Geologic cross section E-E' is the first in a series of cross sections planned by the U.S. Geological Survey (USGS) to document and improve understanding of the geologic framework and petroleum systems of the Appalachian basin. Cross section E-E' provides a regional view of the structural and stratigraphic framework of the basin from the Findlay arch in northwestern Ohio to the Valley and Ridge province in eastern West Virginia, a distance of approximately 380 miles (mi) (fig. 1, on sheet 1). Cross section E-E' updates earlier geologic cross sections through the central Appalachian basin by Renfro and Feray (1970), Bennison (1978), and Bally and Snelson (1980) and a stratigraphic cross section by Colton (1970). Although other published cross sections through parts of the basin show more structural detail (for example, Shumaker, 1985; Kulander and Dean, 1986) and stratigraphic detail (for example, Ryder, 1992; de Witt and others, 1993; Hettinger, 2001), these other cross sections are of more limited extent geographically and stratigraphically. Although specific petroleum systems in the Appalachian basin are not identified on the cross section, many of their key elements (such as source rocks, reservoir rocks, seals, and traps) can be inferred from lithologic units, unconformities, and geologic structures shown on the cross section. Other aspects of petroleum systems (such as the timing of petroleum generation and preferred migration pathways) may be evaluated by burial history, thermal history, and fluid flow models based on information shown on the cross section. Cross section E-E' lacks the detail to illustrate key elements of coal systems (such as paleoclimate, coal quality, and coal rank), but it does provide a general framework (stratigraphic units and general rock types) for the coal-bearing section. Also, cross section E-E' may be used as a reconnaissance tool to identify plausible geologic structures and strata for the subsurface storage of liquid waste (for

  7. Petrographic maturity parameters of a Devonian shale maturation series, Appalachian Basin, USA. ICCP Thermal Indices Working Group interlaboratory exercise

    USGS Publications Warehouse

    Araujo, Carla Viviane; Borrego, Angeles G.; Cardott, Brian; das Chagas, Renata Brenand A.; Flores, Deolinda; Goncalves, Paula; Hackley, Paul C.; Hower, James C.; Kern, Marcio Luciano; Kus, Jolanta; Mastalerz, Maria; Filho, João Graciano Mendonça; de Oliveira Mendonça, Joalice; Rego Menezes, Taissa; Newman, Jane; Suarez-Ruiz, Isabel; Sobrinho da Silva, Frederico; Viegas de Souza, Igor

    2014-01-01

    This paper presents results of an interlaboratory exercise on organic matter optical maturity parameters using a natural maturation series comprised by three Devonian shale samples (Huron Member, Ohio Shale) from the Appalachian Basin, USA. This work was conducted by the Thermal Indices Working Group of the International Committee for Coal and Organic Petrology (ICCP) Commission II (Geological Applications of Organic Petrology). This study aimed to compare: 1. maturation predicted by different types of petrographic parameters (vitrinite reflectance and spectral fluorescence of telalginite), 2. reproducibility of the results for these maturation parameters obtained by different laboratories, and 3. improvements in the spectral fluorescence measurement obtained using modern detection systems in comparison with the results from historical round robin exercises.Mean random vitrinite reflectance measurements presented the highest level of reproducibility (group standard deviation 0.05) for low maturity and reproducibility diminished with increasing maturation (group standard deviation 0.12).Corrected fluorescence spectra, provided by 14 participants, showed a fair to good correspondence. Standard deviation of the mean values for spectral parameters was lowest for the low maturity sample but was also fairly low for higher maturity samples.A significant improvement in the reproducibility of corrected spectral fluorescence curves was obtained in the current exercise compared to a previous investigation of Toarcian organic matter spectra in a maturation series from the Paris Basin. This improvement is demonstrated by lower values of standard deviation and is interpreted to reflect better performance of newer photo-optical measuring systems.Fluorescence parameters measured here are in good agreement with vitrinite reflectance values for the least mature shale but indicate higher maturity than shown by vitrinite reflectance for the two more mature shales. This red shift in

  8. A thrust-ridge paleodepositional model for the Upper Freeport coal bed and associated clastic facies, Upper Potomac coal field, Appalachian basin, U.S.A.

    USGS Publications Warehouse

    Belt, E.S.; Lyons, P.C.

    1989-01-01

    A blind-thrust-ridge model is proposed to explain the lack of coarse clastic material in the vast minable Upper Freeport coal bed (UF). This coal bed contains only fine elastic partings and is overlain by regionally extensive, closely spaced channel-belt deposits in the Upper Potomac coal field of the Appalachian basin. A blind-thrust ridge may have formed a sediment trap and prevented c coarse fluvial sediments from entering the swamp during a period (Westphalian D) when the thick Upper Freeport peat accumulated. Anticlinal thrust ridges and associated depressions may have existed uninterrupted for about 40 km parallel to the Appalachian orogen. Sediment shed from the breached anticlinal ridges accumulated in the sediment trap and was carried out of the ends of the trap by streams that occupied the shear zone at the ends of the blind-thrust ridge. The extent, parallel to the orogen, of thick, areally extensive UF is related to the length of the blind-thrust ridge that, in turn, controlled the spacing of the river-derived coarse clastic sediments that entered the main basin from the east. The thrust plane eventually emerged to the surface of the blind-thrust ridge and peat accumulation was terminated when the ridge became eroded and the sediment trapped behind it was released. The peat was buried by abundant coarse clastic sediment, which formed closely spaced channel belts and intervening flood basins. This model has implications for widespread peat deposits (now coal) that developed in tropical regions a few hundred kilometers from the sea in a tectonically active foreland basin. ?? 1989.

  9. Palynology, petrography and geochemistry of the Sewickley coal bed (Monongahela Group, Late Pennsylvanian), Northern Appalachian Basin, USA

    USGS Publications Warehouse

    Eble, C.F.; Pierce, B.S.; Grady, W.C.

    2003-01-01

    Forty-two bench samples of the Sewickley coal bed were collected from seven localities in the northern Appalachian Basin and analyzed palynologically, petrographically, and geochemically. The Sewickley coal bed occurs in the middle of the Pittsburgh Formation (Monongahela Group) and is of Late Pennsylvanian age. Palynologically, it is dominated by spores of tree ferns. Tree fern spore taxa in the Sewickley include Punctatisporites minutus, Punctatosporites minutus, Laevigatosporites minimus, Spinosporites exiguus, Apiculatasporites saetiger, and Thymospora spp. In fact, Punctatisporites minutus was so abundant that it had to be removed from the standard counts and recorded separately (average 73.2%). Even when Punctatisporites minutus is removed from the counts, tree fern spores still dominate a majority of the assemblages, averaging 64.4%. Among the tree fern spores identified in the Sewickley coal, Thymospora exhibits temporal and spatial abundance variation. Thymospora usually increases in abundance from the base to the top of the bed. Thymospora is also more abundant in columns that are thick (>100 cm) and low in ash yield (< 12.0%, dry basis). Calamite spores (e.g. Calamospora spp., Laevigatosporites minor, and L. vulgaris) are the next most abundant plant group represented in the Sewickley coal, averaging 20%. Contributions from all other plant groups are minor in comparison. Petrographically, the Sewickley coal contains high percentages of vitrinite (average 82.3%, mineral matter-free (mmf)), with structured forms being more common than unstructured forms. In contrast, liptinite and inertinite macerals both occur in low percentages (average 7.7% and 10.0%, respectively). Geochemically, the Sewickley coal has a moderate ash yield (average 12.4%) and high total sulfur content (average 3.4%). Four localities contained a high ash or carbonaceous shale bench. These benches, which may be coeval, are strongly dominated by tree fern spores. Unlike the lower ash

  10. An in situ occurrence of coal balls in the Amburgy coal bed, Pikeville Formation (Duckmantian), central Appalachian Basin, USA

    USGS Publications Warehouse

    Greb, S.F.; Eble, C.F.; Chesnut, D.R.; Phillips, T.L.; Hower, J.C.

    1999-01-01

    Carbonate concretions containing permineralized peat, commonly called coal balls, were encountered in the Amburgy coal, a generally low-ash (9.4%), but commonly high-sulfur (3.6%), Middle Pennsylvanian coal of the Eastern Kentucky Coal Field. These are the first coal balls from the Amburgy coal, and one of only a few reported occurrences from the central Appalachian Basin. The coal balls occur in the upper part of the coal, between two paleochannel cut-outs at the top of the Pikeville Formation, and immediately beneath a scour with a marine fossil lag at the base of the Kendrick Shale Member, Hyden Formation. The coal is thickest (1.3 m) in a narrow (<300 m), elongate depression between the bounding paleochannels, and thins toward the occurrence of coal balls. Total biovolume as measured from acetate peels of coal balls indicates cordaites or lycopsid (36.1% each) dominance. Vertical sampling through one coal-ball aggregate shows zoning from a lower cordaites-dominant (88.7%) assemblage, to a middle, degraded, sphenopsid-rich assemblage, to an upper lycopsid-dominant (88.6%) assemblage. Beneath the coal balls, palynologic and petrographic analyses indicate the basal and middle portions of the bed are dominated by arborescent lycopsid spores and cordaites pollen, and by vitrinite macerals. The top part of the bed, above the coal balls, contains increased intertinite macerals, increased percentages of small fern spores, and variable ash yield (5-21%). Thickening of the Amburgy coal along a structural low, in combination with basal high-ash yields, vitrinite-dominance, and heterogenous palynoflora, indicate paleotopographic control on initial peat accumulation. Abundant lycopsid spores in the basal and middle part of the coal reflect rheotrophic conditions consistent with accumulation in a paleotopographic depression. Apparent zonation preserved in one of the coal-ball masses may document plant successions in response to flooding. Similar percentages of cordaites and

  11. Exploration in the Ombilin Intermontane Basin, West Sumatra

    SciTech Connect

    Koning, T. Petroleum Co., Lagos )

    1996-01-01

    The Ombilin Basin is a Tertiary intermontane basin located within the Barisan Mountain Range of Sumatra. Oil exploration commenced in the Ombilin Basin in the early 1980s when geological mapping was carried out, a synthetic aperture radar survey was flown, and a basin-wide geophysical survey was completed. This effort led to the drilling of Sinimar No. 1 to a total depth 3020 m. Sinimar No. 1 was a historic well in Indonesia's oil industry since it was the first oil exploration well drilled in the Ombilin Basin and also the first well drilled in an intermontane basin in Indonesia. Oil, gas and condensate was tested in the well. An integrated interpretation of the well, geophysical and outcrop data indicates that despite its small areal size (30 km x 50 km), the Ombilin Basin is a deep pull-apart basin containing up to 4500 m of Tertiary sediments, ranging in age from Middle Eocene to Early Miocene. The basin currently is in an intermontane basin structural setting but it was also an intermontane basin during its Early Tertiary depositional history. During the Eocene, alluvial fans and massive debris flows were deposited on the basin margins and a large lake occupied the basin center. Fluvial deposition occurred in the basin during the Oligocene followed by deposition of marine shales, sandstones, and isolated reefs during the Miocene. Although the Ombilin Basin is located within Sumatra's magmatic arc and is partially covered by volcanics from extinct and active volcanoes, the subsurface temperature gradients of 1.62 deg. F/100 ft. recorded in Sinimar No. I and 1.47 deg F/100 ft. measured in a deep (670 m) coal exploration core hole are significantly cooler than the average subsurface temperature gradients in the Sumatra back-arc basins. Organic-rich Eocene lacustrine shales are the likely source rocks for the hydrocarbons tested in Sinimar No. 1 and the oil seeps located along the basin margins.

  12. Exploration in the Ombilin Intermontane Basin, West Sumatra

    SciTech Connect

    Koning, T.

    1996-12-31

    The Ombilin Basin is a Tertiary intermontane basin located within the Barisan Mountain Range of Sumatra. Oil exploration commenced in the Ombilin Basin in the early 1980s when geological mapping was carried out, a synthetic aperture radar survey was flown, and a basin-wide geophysical survey was completed. This effort led to the drilling of Sinimar No. 1 to a total depth 3020 m. Sinimar No. 1 was a historic well in Indonesia`s oil industry since it was the first oil exploration well drilled in the Ombilin Basin and also the first well drilled in an intermontane basin in Indonesia. Oil, gas and condensate was tested in the well. An integrated interpretation of the well, geophysical and outcrop data indicates that despite its small areal size (30 km x 50 km), the Ombilin Basin is a deep pull-apart basin containing up to 4500 m of Tertiary sediments, ranging in age from Middle Eocene to Early Miocene. The basin currently is in an intermontane basin structural setting but it was also an intermontane basin during its Early Tertiary depositional history. During the Eocene, alluvial fans and massive debris flows were deposited on the basin margins and a large lake occupied the basin center. Fluvial deposition occurred in the basin during the Oligocene followed by deposition of marine shales, sandstones, and isolated reefs during the Miocene. Although the Ombilin Basin is located within Sumatra`s magmatic arc and is partially covered by volcanics from extinct and active volcanoes, the subsurface temperature gradients of 1.62 deg. F/100 ft. recorded in Sinimar No. I and 1.47 deg F/100 ft. measured in a deep (670 m) coal exploration core hole are significantly cooler than the average subsurface temperature gradients in the Sumatra back-arc basins. Organic-rich Eocene lacustrine shales are the likely source rocks for the hydrocarbons tested in Sinimar No. 1 and the oil seeps located along the basin margins.

  13. Assessment of the Geologic Carbon Dioxide Storage Resources of the Clinton, Medina, and Tuscarora Formations in the Appalachian Basin

    NASA Astrophysics Data System (ADS)

    Doolan, C.

    2013-12-01

    The U.S. Geological Survey (USGS) has completed an assessment of the geologic carbon dioxide (CO2) storage potential within the Appalachian Basin. This assessment was performed as part of the USGS national assessment of geologic CO2 storage resources in which individual sedimentary basins are divided into storage assessment units (SAUs) based on geologic characteristics such as lithology, porosity, permeability, reservoir depth, formation water salinity, and the presence of a regional sealing formation. This study focuses on the assessment of the Clinton, Medina and Tuscarora Formations storage assessment unit (SAU) that covers an area of 48.9 million acres in eastern Kentucky and Ohio, West Virginia, northern and western Pennsylvania, and southwestern New York. The areal extent of the SAU is defined on the western boundary by the 100 foot isopach contour of the combined Rochester and Rose Hill Shales that acts as the regional sealing formation and is defined by the 3,000 foot depth to top contour of the Clinton and Tuscarora Formations elsewhere. Depth-to-top and isopach contours were derived from IHS Energy Group, 2011 data for over 25,000 unique boreholes located throughout the area of the SAU. The Clinton, Medina and Tuscarora Formations SAU is composed of the porous intervals of the Lower to Middle Silurian strata that is bounded by the underlying Ordovician age Queenston Shale, and the overlying Silurian age Rochester and Rose Hill Shales. Porous intervals were deposited in a variety of wave and tidal dominated environments as a result of a Lower Silurian shoreline that prograded southeast to northwest. Porous units in the Tuscarora Formation in southwestern and central Pennsylvania and West Virginia are predominantly fine to medium grained sands of alluvial plain facies and those of the Clinton and Medina Formations in southwestern New York, northeastern Pennsylvania, eastern Ohio and northeastern Kentucky are typically fine grained quartzarenites deposited

  14. A direct comparison of the ages of detrital monazite versus detrital zircon in Appalachian foreland basin sandstones: Searching for the record of Phanerozoic orogenic events

    NASA Astrophysics Data System (ADS)

    Hietpas, Jack; Samson, Scott; Moecher, David

    2011-10-01

    The provenance potential of detrital monazite was investigated by in situ measurement of 232Th- 208Pb dates of grains isolated from six Middle Carboniferous-Permian sandstones from the Appalachian foreland basin. Provenance assessment of these units was previously investigated by measuring U-Pb crystallization ages of detrital zircon (Thomas et al., 2004; Becker et al., 2005, 2006). Approximately 90% of the detrital zircon ages record Mesoproterozoic or older ages, with only 10% recording the three major pulses of tectonism (Taconian, Acadian and Alleghanian) that are the hallmark of the Appalachian Orogen. 232Th- 208Pb ages of detrital monazite, however, strongly record the complex phases of Paleozoic orogenesis. Nearly 65% of the ages record Paleozoic events, while 35% record Neoproterozoic or older ages. In several of the analyzed sandstones, detrital monazite ages record Paleozoic orogenic events that are completely missed by detrital zircon ages, demonstrating that monazite ages more accurately reflect the character of the sediment source rocks. The inferred maximum age of sediment deposition, as determined by the youngest monazite grains, is ~ 550 Ma younger for two of the analyzed sandstones compared to depositional constraints based on the youngest detrital zircon. The different physical properties and petrogenesis of zircon and monazite are interpreted to be factors for the dramatic differences in sediment provenance information provided by each mineral. The results from this study have important implications for determining sediment provenance, constraining maximum age of sediment deposition, and developing robust regional tectonic models.

  15. Examples from the atlas of major Appalachian Gas Plays

    SciTech Connect

    Patchen, D.G.; Aminian, K.; Avary, K.L.; Baranoski, M.T.; Flaherty, K.; Nuttall, B.C.; Smosna, R.A.

    1993-12-31

    The objectives of this contract are to produce a panted atlas of major Appalachian basin gas plays and to compile a machine-readable database of reservoir data. The Appalachian Oil and Natural Gas Research Consortium (AONGRC or the Consortium), a partnership of the state geological surveys in Kentucky, Ohio, Pennsylvania, and West Virginia, and the departments of Geology and Petroleum and Natural Gas Engineering at West Virginia University (WVU), agrees with the need to classify gas reservoirs by geologic plays. During meetings with industry representatives, the small independents in the basin emphasized that one of their prime needs was to place each producing reservoir within a stratigraphic framework subdivided by environment of deposition to enable them to develop exploration and development strategies. The text for eight of the 31 play descriptions has been completed, drafting of illustrations for these plays is underway (or complete for some plays), and the review process is ongoing.

  16. Coalbed methane potential in the Appalachian states of Pennsylvania, West Virginia, Maryland, Ohio, Virginia, Kentucky, and Tennessee; an overview

    USGS Publications Warehouse

    Lyons, Paul C.

    1996-01-01

    Ricei s (1995) report. This compares with 20 Tcf in place and 2.30 Tcf as technically recoverable CBM for the Black Warrior Basin. These estimates should be considered preliminary because of unknown CBM potential in Ohio, Maryland, Tennessee, and eastern Kentucky. The largest potential for CBM development in the central Appalachian basin is in the Pocahontas coal beds, which have total gas values as much as 700 cf/ton, and in the New River coal beds. In the northern Appalachian basin, the greatest CBM potential is in the Middle Pennsylvanian Allegheny coal beds, which have total gas values as much as 252 cf/ton. Rice (1995) estimated a mean estimated ultimate recovery per well of 521 MMcfg for the central Appalachian basin and means of 121 and 216 MMcfg for the anticlinal and synclinal areas, respectively, of the northern Applachian basin. There is potential for CBM development in the Valley coal fields and Richmond basin of Virginia, the bituminous region of southeastern Kentucky, eastern Ohio, northern Tennessee, and the Georges Creek coal field of western Maryland and adjacent parts of Pennsylvania. Moreover, the Anthracite region of eastern Pennsylvania, which has the second highest known total gas content for a single coal bed (687 cf/ton) in the central and northern Appalachian basin, should be considered to have a fair to good potential for CBM development where structure, bed continuity, and permeability are favorable. CBM is mainly an undeveloped unconventional fossil-fuel resource in the central and northern Appalachian basin states, except in Virginia, and will probably contribute an increasing part of total Appalachian gas production into the next century as development in Pennsylvania, West Virginia, Ohio, and other Appalachian states continue. The central and northern Appalachian basins are frontier or emerging regions for CBM exploration and development, which will probably extend well into the next century. On the basis of CBM production

  17. Log ASCII Standard (LAS) Files for Geophysical (Gamma Ray) Wireline Well Logs and Their Application to Geologic Cross Section C-C' Through the Central Appalachian Basin

    USGS Publications Warehouse

    Trippi, Michael H.; Crangle, Robert D.

    2009-01-01

    U.S. Geological Survey (USGS) regional geologic cross section C-C' (Ryder and others, 2008) displays key stratigraphic intervals in the central Appalachian basin. For this cross section, strata were correlated by using descriptions of well cuttings and gamma ray well log traces. This report summarizes the procedures used to convert gamma ray curves on paper well logs to the digital Log ASCII (American Standard Code for Information Interchange) Standard (LAS) format using the third-party software application Neuralog. The procedures could be used with other geophysical wireline logs also. The creation of digital LAS files from paper well logs by using Neuralog is very helpful, especially when dealing with older logs with limited or nonexistent digital data. The LAS files from the gamma ray logs of 11 wells used to construct cross section C-C' are included in this report. They may be downloaded from the index page as a single ZIP file.

  18. Part I: Neoacadian to Alleghanian foreland basin development and provenance in the central appalachian orogen, pine mountain thrust sheet Part II: Structural configuration of a modified Mesozoic to Cenozoic forearc basin system, south-central Alaska

    NASA Astrophysics Data System (ADS)

    Robertson, Peter Benjamin

    Foreland and forearc basins are large sediment repositories that form in response to tectonic loading and lithospheric flexure during orogenesis along convergent plate boundaries. In addition to their numerous valuable natural resources, these systems preserve important geologic information regarding the timing and intensity of deformation, uplift and erosion history, and subsidence history along collisional margins, and, in ancient systems, may provide more macroscopic information regarding climate, plate motion, and eustatic sea level fluctuations. This thesis presents two studies focused in the Paleozoic Appalachian foreland basin system along the eastern United States and in the Mesozoic to Cenozoic Matanuska forearc basin system in south-central Alaska. Strata of the Appalachian foreland basin system preserve the dynamic history of orogenesis and sediment dispersal along the east Laurentian margin, recording multiple episodes of deformation and basin development during Paleozoic time. A well-exposed, >600 m thick measured stratigraphic section of the Pine Mountain thrust sheet at Pound Gap, Kentucky affords one of the most complete exposures of Upper Devonian through Middle Pennsylvanian strata in the basin. These strata provide a window into which the foreland basin's development during two major collisional events known as the Acadian-Neoacadian and the Alleghanian orogenies can be observed. Lithofacies analysis of four major sedimentary successions observed in hanging wall strata record the upward transition from (1) a submarine deltaic fan complex developed on a distal to proximal prodelta in Late Devonian to Middle Mississippian time, to (2) a Middle to Late Mississippian carbonate bank system developed on a slowly subsiding, distal foreland ramp, which was drowned by (3) Late Mississippian renewed clastic influx to a tidally influenced, coastal deltaic complex to fluvial delta plain system unconformably overlain by (4) a fluvial braided river complex

  19. Properties, origin and nomenclature of rodlets of the inertinite maceral group in coals of the central Appalachian basin, U.S.A.

    USGS Publications Warehouse

    Lyons, P.C.; Finkelman, R.B.; Thompson, C.L.; Brown, F.W.; Hatcher, P.G.

    1982-01-01

    Resin rodlets, sclerenchyma strands and woody splinters, which are collectively called rodlets, were studied by chemical, optical petrographic, and scanning-electron microscopic (SEM) techniques. A study was made of such rodlets from the bituminous coal beds of the central Appalachian basin (Pennsylvanian; Upper Carboniferous) of the United States. Comparisons were made with rodlets from coal beds of the Illinois basin, the Southern Anthracite Field of Pennsylvania, the St. Rose coal field of Nova Scotia, and European and other coal fields. In order to determine their physical and chemical properties, a detailed study was made of the rodlets from the Pomeroy coal bed (high volatile A bituminous coal; Monongahela Formation; Upper Pennsylvanian) of Kanawha County, West Virginia. The origin of the rodlets was determined by a comparative analysis of a medullosan (seed fern) stem from the Herrin (No. 6) coal bed (high volatile C bituminous coal; Carbondale Formation) from Washington County, Illinois. Rodlets are commonly concentrated in fusain or carbominerite layers or lenses in bituminous coal beds of the central Appalachian basin. Most of the rodlets examined in our study were probably derived from medullosan seed ferns. The three types of rodlets are distinguished on the basis of cellularity, morphology and fracture. The resin rodlets studied by us are noncellular and appear to be similar in properties and origin to those found in coal beds of the Middle and Upper Pennsylvanian of the Illinois basin. The resin rodlets extracted from the Pomeroy coal bed exhibit high relief and high reflectance when polished and viewed in reflected light; they are opaque in transmitted light. In cross section, the resin rodlets are oval to round and have diameters ranging from 60 to 450 ??m. Many are solid, but some have vesicles, canals or cavities, which are commonly filled with clay, probably kaolinite. Typically, they have distinct fracture patterns ("kerfs") in longitudinal and

  20. Appalachian Mountains

    Atmospheric Science Data Center

    2014-05-15

    ... angle, the line-of-sight through the atmosphere is three times longer, and a thin pall of haze over the Appalachians is significantly ... D.C. The Terra spacecraft is managed by NASA's Goddard Space Flight Center, Greenbelt, MD. The MISR data were obtained from the NASA Langley ...

  1. APPALACHIAN VOLUNTEERS.

    ERIC Educational Resources Information Center

    1964

    COLLEGE STUDENT VOLUNTEERS WORKING IN THE ISOLATED AREAS OF EASTERN KENTUCKY HAVE INSTITUTED A PROGRAM DESIGNED TO AID IN THE WAR ON POVERTY. THE APPALACHIAN VOLUNTEERS WERE INITIALLY SUPPORTED BY A GRANT FROM THE AREA REDEVELOPMENT ADMINISTRATION AND BY CONTRIBUTIONS, FROM PRIVATE CORPORATIONS AND FOUNDATIONS, OF MONEY AND MATERIALS. GROUNDWORK…

  2. Regional geological assessment of the Devonian-Mississippian shale sequence of the Appalachian, Illinois, and Michigan basins relative to potential storage/disposal of radioactive wastes

    SciTech Connect

    Lomenick, T.F.; Gonzales, S.; Johnson, K.S.; Byerly, D.

    1983-01-01

    The thick and regionally extensive sequence of shales and associated clastic sedimentary rocks of Late Devonian and Early Mississippian age has been considered among the nonsalt geologies for deep subsurface containment of high-level radioactive wastes. This report examines some of the regional and basin-specific characteristics of the black and associated nonblack shales of this sequence within the Appalachian, Illinois, and Michigan basins of the north-central and eastern United States. Principal areas where the thickness and depth of this shale sequence are sufficient to warrant further evaluation are identified, but no attempt is made to identify specific storage/disposal sites. Also identified are other areas with less promise for further study because of known potential conflicts such as geologic-hydrologic factors, competing subsurface priorities involving mineral resources and groundwater, or other parameters. Data have been compiled for each basin in an effort to indicate thickness, distribution, and depth relationships for the entire shale sequence as well as individual shale units in the sequence. Included as parts of this geologic assessment are isopach, depth information, structure contour, tectonic elements, and energy-resource maps covering the three basins. Summary evaluations are given for each basin as well as an overall general evaluation of the waste storage/disposal potential of the Devonian-Mississippian shale sequence,including recommendations for future studies to more fully characterize the shale sequence for that purpose. Based on data compiled in this cursory investigation, certain rock units have reasonable promise for radioactive waste storage/disposal and do warrant additional study.

  3. Evolution of Cambrian-Ordovician carbonate shelf, United States Appalachians

    SciTech Connect

    Read, J.F.

    1985-02-01

    Cross sections and isopach maps (palinspastic) of the Cambrian-Ordovician continental shelf, US Appalachians, show that thickness and facies trends are controlled by the Adirondack, New Jersey, and Virginia highs and depocenters in Tennessee, Pennsylvania, and by the Rome trough. Carbonate sedimentation was initiated with drowning of Early Cambrian clastics, deposition of carbonate ramp and rimmed shelf facies followed by drowning, then regional regression and deposition of Early to Middle Cambrian red beds and platform margin rimmed shelf facies. During subsequent regional transgression, the Conasauga intrashelf shale basin formed, bounded toward the shelf edge and along depositional strike by Middle to Upper Cambrian oolitic ramp facies and cyclic peritidal carbonates. Intrashelf basin filling and regional regression caused progradation of Late Cambrian cyclic carbonates and clastics across the shelf. By this time, the margin had a relief of 2.5 km. During the Early Ordovician, incipient drowning of the shelf formed subtidal carbonates and bioherms that passed up into cyclic carbonate as sea level oscillations decreased in magnitude. Numerous unconformities interrupt this sequence in the northern Appalachians. The earlier high relief rimmed shelf was converted into a ramp, owing to uplift in the basin, heralding approaching collision. Subsidence rates on the margin were low (4 cm/1000 yr) and typical of a mature passive margin. Shelf sedimentation in the southern Appalachians ceased with arc-continent collision and development of the Knox unconformity, which dies out into the Pennsylvania depocenter. Major exploration targets are in the Late Cambrian-Early Ordovician Knox Group.

  4. Exploration in Ordovician of central Michigan Basin

    SciTech Connect

    Fisher, J.H.; Barratt, M.W.

    1985-12-01

    Deep wells in the central Michigan basin have provided sufficient data to define two new mappable formations - the Foster Formation and the Bruggers Formation. Recent conodont studies have corrected the age assignments of the strata containing these formations. Previously, the lower section (Foster) was classified as mostly Cambrian, and the upper unit (Bruggers) was identified as Early Ordovician. Conodont identifications indicate an Early and Middle Ordovician age for the Foster Formation and a Middle Ordovician age for the Bruggers Formation. The Michigan basin existed in embryonic form in the Late Cambrian, but the full outline of the present-day basin did not develop until Early Ordovician. Gas and condensate are produced from the Bruggers Formation as deep as 11,252 ft (3429 m). Geothermal investigations suggest that gas production is possible to the base of the Paleozoic section in the central basin (17,000 ft or 5181 m). Paleotemperatures were higher during the Paleozoic owing to 3000-4000 ft (914-1291 m) of additional sedimentary cover. Five wells are producing from the Bruggers Formation. All are deeper tests in anticlines producing from Devonian reservoirs discovered earlier. The structures are the result of vertical movements of basement fault blocks activated by regional stresses. 12 figures, 2 tables.

  5. Eustatic control on early dolomitization of cyclic peritidal carbonates: Evidence from the Early Ordovician Upper Knox Group, Appalachians and Middle to Late Cambrian Bonanza King Formation, southern Great basin

    SciTech Connect

    Montanez, I.P. )

    1991-03-01

    The origin of massive dolomite in ancient cyclic carbonate successions remains a poorly resolved issue reflecting the lack of modern analogs of extensive dolomitization. This paper presents evidence for extensive synsedimentary dolomitization of peritidal cyclic carbonates of the Early Ordovician upper Knox Group, Appalachians, and of the Middle to Late Cambrian Bonanza King Formation, southern Great basin. Early dolomitization of these Cambro-Ordovician carbonates was synchronous with regressive conditions governed by superimposed sea-level oscillations (fifth-, fourth-, and third-order).

  6. Burial and thermal history of the central Appalachian basin, based on three 2-D models of Ohio, Pennsylvania, and West Virginia

    USGS Publications Warehouse

    Rowan, Elisabeth L.

    2006-01-01

    Introduction: Three regional-scale, cross sectional (2-D) burial and thermal history models are presented for the central Appalachian basin based on the detailed geologic cross sections of Ryder and others (2004), Crangle and others (2005), and Ryder, R.T., written communication. The models integrate the available thermal and geologic information to constrain the burial, uplift, and erosion history of the region. The models are restricted to the relatively undeformed part of the basin and extend from the Rome trough in West Virginia and Pennsylvania northwestward to the Findlay arch in Ohio. This study expands the scope of previous work by Rowan and others (2004) which presented a preliminary burial/thermal history model for a cross section (E-E') through West Virginia and Ohio. In the current study, the burial/thermal history model for E-E' is revised, and integrated with results of two additional cross sectional models (D-D' and C-C'). The burial/thermal history models provide calculated thermal maturity (Ro%) values for the entire stratigraphic sequence, including hydrocarbon source rocks, along each of the three cross sections. In contrast, the Ro and conodont CAI data available in the literature are sparse and limited to specific stratigraphic intervals. The burial/thermal history models also provide the regional temperature and pressure framework that is needed to model hydrocarbon migration.

  7. Petroleum exploration in Absaroka basin of northwestern Wyoming

    SciTech Connect

    Sundell, K.A.

    1986-08-01

    A new, virtually unexplored petroleum province with large potential resources can be defined in northwestern Wyoming. Structurally, the Absaroka basin is bounded on the north by the Beartooth uplift, to the west by the Gallatin and Washakie uplifts, to the south by the Washakie and Owl Creek uplifts, and to the east by the Cody arch. The Cody arch connects the southern Beartooth uplift with the northwesternmost Owl Creek uplift and separates the Bighorn basin to the east from the Absaroka basin to the west. The eastern flank of the cody arch is bounded by a major west-dipping thrust fault. The western flank is locally a subhorizontal shelf but overall gently dips to the west-southwest into deeper parts of the Absaroka basin. In contrast to most petroleum basins, the Absaroka basin is topographically a rugged mountain range, created by erosion of a thick sequence of Eocene volcanic rocks that fill the center of the basin and lap onto the adjacent uplifts. Mesozoic and Paleozoic rocks that have produced several billion barrels of oil from the adjacent Bighorn and Wind River basins are probably present within the Absaroka basin and should have similar production capabilities. The Absaroka basin may have greater potential than adjacent basins because the volcanics provide additional traps and reservoirs. Domes in Mesozoic and Paleozoic rocks beneath the volcanics and stratigraphic traps at the angular unconformity between the volcanics and underlying reservoirs are primary exploration targets. Unique geologic, geophysical, permitting, access, and drilling problems are encountered in all aspects of exploration.

  8. Petroleum in the Caribbean Basin: Further exploration justified?

    SciTech Connect

    Robinson, E.

    1996-08-01

    After more than half a century of exploration for petroleum in that part of the Caribbean Basin covered by this review, the prospects for substantial discoveries remain low. Only Barbados has had modest but sustained production of oil and gas. In Hispaniola minor production from small prospects lasted briefly. Exploration in the northeast Caribbean has not resulted in discoveries. Similar exploration in Puerto Rico and, on a more extensive scale, in Jamaica, has also failed to show positive results. On the Nicaragua Rise (Mosquitia, Tela Basins) drilling has produced shows but no production, a situation also evident in Belize. Nevertheless, examination of these results, in the context of the regional geology of the Caribbean Basin, suggests there are areas where further exploration is justified.

  9. SECONDARY NATURAL GAS RECOVERY IN THE APPALACHIAN BASIN: APPLICATION OF ADVANCED TECHNOLOGIES IN A FIELD DEMONSTRATION SITE, HENDERSON DOME, WESTERN PENNSYLVANIA

    SciTech Connect

    Douglas G. Patchen

    2000-12-01

    Two independent high-resolution aeromagnetic surveys flown by Airmag Surveys, Inc. and interpreted by Pearson, de Ridder and Johnson, Inc were merged, processed and reinterpreted by Pearson, de Ridder and Johnson, Inc for this study. Derived products included depth filtered and reduced to pole maps of total magnetic intensity, vertical and horizontal gradients, interpreted STARMAG structure, lineament analysis and an overall interpretation. The total magnetic intensity patterns of the combined survey conformed reasonably well to those of coarser grid, non-proprietary regional aeromagnetic surveys reviewed. The merged study also helped illustrate regional basement patterns adjacent to and including the northwest edge of the Rome trough. The tectonic grain interpreted is dominantly southwest-northeast with a secondary northwest-southeast component that is consistent with this portion of the Appalachian basin. Magnetic susceptibility appears to be more important locally than basement structure in contributing to the magnetic intensity recorded, based on seismic to aeromagnetic data comparisons made to date. However, significant basement structures cannot be ruled out for this area, and in fact are strongly suspected to be present. The coincidence of the Henderson Dome with a total magnetic intensity low is an intriguing observation that suggests the possibility that structure in the overlying Lower Paleozoic section may be detached from the basement. Rose diagrams of lineament orientations for 2.5 minute unit areas are more practical to use than the full-quadrangle summaries because they focus on smaller areas and involve less averaging. Many of these illustrate a northeast bias. Where orientations abruptly become scattered, there is an indication of intersecting fractures and possible exploration interest. However, the surface lineament study results are less applicable in a practical sense relative to the seismic, subsurface or aeromagnetic control used

  10. Apatite fission-track thermochronology of the Appalachian foreland basin from the Virginia Piedmont to eastern Ohio

    SciTech Connect

    Roden, M.K. . Dept. of Earth and Environmental Science); Cerveny, P.F.; Bergman, S.C. . Research and Technical Services)

    1992-01-01

    Apatite fission-track ages have been determined for 29 samples from two transects in the southern Appalachians. The northern transect extends from the VA Piedmont northwest through the Valley and Ridge Province, Cumberland Plateau, and into the Appalachian foreland of southeastern OH. An additional transect was collected from the Pine Mountain thrust in southeastern KY extending northwest to the Cincinnati Arch. Precambrian gneisses and granites from the VA Piedmont yield reset apatite fission-track ages ranging from 103 [+-] 6 to 138 [+-] 11 Ma. Ordovician through Mississippian sedimentary rocks from the Valley and Ridge Province of VA-WV also yield reset apatite fission-track ages ranging from 120 [+-] 8 to 144 [+-] 20 Ma. The cooling histories for the Piedmont and Valley and Ridge rocks of VA and WV thus appear similar, having cooled rapidly between about 103 and 144 Ma. Pennsylvanian samples from the Cumberland Plateau of WV yield rest apatite fission-track ages of 112 [+-] 7 to 169 [+-] 13 MA in the southeast which grade into partially reset (mixed ages) northwest of Charlestown (133 [+-] 13 to 156 [+-] 10 Ma). The Permian Dunkard Formation from the OH-WV border yielded a mixed age of 197 [+-] 13 Ma, suggesting that the Permian has not been subjected to temperatures > 100 C for times greater than 1 Ma, since it was deposited. Mississippian--Pennsylvanian samples from eastern KY yield reset apatite fission-track ages which decrease from the Pine Mt. Thrust (186 [+-] 16 Ma) to Mozelle, KY (136 [+-] 12 Ma), then increase toward the Cincinnati Arch (166 [+-] 18 [minus] 186 [+-] 21 Ma). This is consistent with older apatite fission-track ages (200 Ma) from Ordovician K-bentonites in the vicinity of the Cincinnati Arch.

  11. Visayan Basin - the birthplace of Philippine petroleum exploration revisited

    SciTech Connect

    Rillera, F.G. ); Durkee, E.F. )

    1994-07-01

    Petroleum exploration in the Philippines has its roots in the Visayan Basin in the central Philippines. This is a Tertiary basin with up to 30,000 ft of sedimentary fill. With numerous surface oil and gas manifestations known as early as 1888, the area was the site of the first attempts to establish commercial petroleum production in the country. Over the past 100 years, more than 200 wells have been drilled in the basin. Several of these have yielded significant oil and gas shows. Production, albeit noncommercial in scale, has been demonstrated to be present in some places. A review of past exploration data reveals that many of the earlier efforts failed due to poorly located tests from both structural and stratigraphic standpoints. Poor drilling and completion technology and lack of funding compounded the problems of early explorationists. Because of this, the basin remains relatively underexplored. A recent assessment by COPLEX and E.F. Durkee and Associates demonstrates the presence of many untested prospects in the basin. These prospects may contain recoverable oil and gas potential on the order of 5 to 10 MMBO onshore and 25 to 100 MMBO offshore. With new exploration ideas, innovative development concepts, and the benefit of modern technology, commercial oil and gas production from the basin may yet be realized.

  12. Depletion of Appalachian coal reserves - how soon?

    USGS Publications Warehouse

    Milici, R.C.

    2000-01-01

    Much of the coal consumed in the US since the end of the last century has been produced from the Pennsylvanian strata of the Appalachian basin. Even though quantities mined in the past are less than they are today, this basin yielded from 70% to 80% of the nation's annual coal production from the end of the last century until the early 1970s. During the last 25 years, the proportion of the nation's coal that was produced annually from the Appalachian basin has declined markedly, and today it is only about 40% of the total. The amount of coal produced annually in the Appalachian basin, however, has been rising slowly over the last several decades, and has ranged generally from 400 to 500 million tons (Mt) per year. A large proportion of Appalachian historical production has come from relatively few counties in southwestern Pennsylvania, northern and southern West Virginia, eastern Kentucky, Virginia and Alabama. Many of these counties are decades past their years of peak production and several are almost depleted of economic deposits of coal. Because the current major consumer of Appalachian coal is the electric power industry, coal quality, especially sulfur content, has a great impact on its marketability. High-sulfur coal deposits in western Pennsylvania and Ohio are in low demand when compared with the lower sulfur coals of Virginia and southern West Virginia. Only five counties in the basin that have produced 500 Mt or more exhibit increasing rates of production at relatively high levels. Of these, six are in the central part of the basin and only one, Greene County, Pennsylvania, is in the northern part of the basin. Decline rate models, based on production decline rates and the decline rate of the estimated, 'potential' reserve, indicate that Appalachian basin annual coal production will be 200 Mt or less by the middle of the next century. Published by Elsevier Science B.V.Much of the coal consumed in the US since the end of the last century has been produced

  13. Annual and average estimates of water-budget components based on hydrograph separation and PRISM precipitation for gaged basins in the Appalachian Plateaus Region, 1900-2011

    USGS Publications Warehouse

    Nelms, David L.; Messinger, Terence; McCoy, Kurt J.

    2015-01-01

    As part of the U.S. Geological Survey’s Groundwater Resources Program study of the Appalachian Plateaus aquifers, annual and average estimates of water-budget components based on hydrograph separation and precipitation data from parameter-elevation regressions on independent slopes model (PRISM) were determined at 849 continuous-record streamflow-gaging stations from Mississippi to New York and covered the period of 1900 to 2011. Only complete calendar years (January to December) of streamflow record at each gage were used to determine estimates of base flow, which is that part of streamflow attributed to groundwater discharge; such estimates can serve as a proxy for annual recharge. For each year, estimates of annual base flow, runoff, and base-flow index were determined using computer programs—PART, HYSEP, and BFI—that have automated the separation procedures. These streamflow-hydrograph analysis methods are provided with version 1.0 of the U.S. Geological Survey Groundwater Toolbox, which is a new program that provides graphing, mapping, and analysis capabilities in a Windows environment. Annual values of precipitation were estimated by calculating the average of cell values intercepted by basin boundaries where previously defined in the GAGES–II dataset. Estimates of annual evapotranspiration were then calculated from the difference between precipitation and streamflow.

  14. Log ASCII Standard (LAS) Files for Geophysical Wireline Well Logs and Their Application to Geologic Cross Sections Through the Central Appalachian Basin

    USGS Publications Warehouse

    Crangle, Robert D.

    2007-01-01

    Introduction The U.S. Geological Survey (USGS) uses geophysical wireline well logs for a variety of purposes, including stratigraphic correlation (Hettinger, 2001, Ryder, 2002), petroleum reservoir analyses (Nelson and Bird, 2005), aquifer studies (Balch, 1988), and synthetic seismic profiles (Kulander and Ryder, 2005). Commonly, well logs are easier to visualize, manipulate, and interpret when available in a digital format. In recent geologic cross sections E-E' and D-D', constructed through the central Appalachian basin (Ryder, Swezey, and others, in press; Ryder, Crangle, and others, in press), gamma ray well log traces and lithologic logs were used to correlate key stratigraphic intervals (Fig. 1). The stratigraphy and structure of the cross sections are illustrated through the use of graphical software applications (e.g., Adobe Illustrator). The gamma ray traces were digitized in Neuralog (proprietary software) from paper well logs and converted to a Log ASCII Standard (LAS) format. Once converted, the LAS files were transformed to images through an LAS-reader application (e.g., GeoGraphix Prizm) and then overlain in positions adjacent to well locations, used for stratigraphic control, on each cross section. This report summarizes the procedures used to convert paper logs to a digital LAS format using a third-party software application, Neuralog. Included in this report are LAS files for sixteen wells used in geologic cross section E-E' (Table 1) and thirteen wells used in geologic cross section D-D' (Table 2).

  15. Annual and average estimates of water-budget components based on hydrograph separation and PRISM precipitation for gaged basins in the Appalachian Plateaus Region, 1900-2011

    USGS Publications Warehouse

    Nelms, David L.; Messinger, Terence; McCoy, Kurt J.

    2015-07-14

    As part of the U.S. Geological Survey’s Groundwater Resources Program study of the Appalachian Plateaus aquifers, annual and average estimates of water-budget components based on hydrograph separation and precipitation data from parameter-elevation regressions on independent slopes model (PRISM) were determined at 849 continuous-record streamflow-gaging stations from Mississippi to New York and covered the period of 1900 to 2011. Only complete calendar years (January to December) of streamflow record at each gage were used to determine estimates of base flow, which is that part of streamflow attributed to groundwater discharge; such estimates can serve as a proxy for annual recharge. For each year, estimates of annual base flow, runoff, and base-flow index were determined using computer programs—PART, HYSEP, and BFI—that have automated the separation procedures. These streamflow-hydrograph analysis methods are provided with version 1.0 of the U.S. Geological Survey Groundwater Toolbox, which is a new program that provides graphing, mapping, and analysis capabilities in a Windows environment. Annual values of precipitation were estimated by calculating the average of cell values intercepted by basin boundaries where previously defined in the GAGES–II dataset. Estimates of annual evapotranspiration were then calculated from the difference between precipitation and streamflow.

  16. Stratigraphic Framework of Cambrian and Ordovician Rocks in the Appalachian Basin from Sequatchie County, Tennessee, through Eastern Kentucky, to Mingo County, West Virginia

    USGS Publications Warehouse

    Ryder, Robert T.; Crangle, Robert D.; Repetski, John E.; Harris, Anita G.

    2008-01-01

    Cross section H-H' is the seventh in a series of restored cross sections constructed by the lead author to show the stratigraphic framework of Cambrian and Ordovician rocks in the Appalachian basin from Pennsylvania to Tennessee. The sections show complexly intertongued carbonate and siliciclastic lithofacies, marked thickness variations, key marker horizons, unconformities, stratigraphic nomenclature of the Cambrian and Ordovician sequence, and major faults that offset Proterozoic basement and overlying lower Paleozoic rocks. Several of the drill holes along the cross section have yielded a variety of whole and (or) fragmented conodont elements. The identifiable conodonts are used to differentiate strata of Late Cambrian, Early Ordovician, and Middle Ordovician age, and their conodont color alteration index (CAI) values are used to establish the thermal maturity of the sequence. Previous cross sections in this series are G-G', F-F', E-E', D-D', C-C', and B-B'. Many of these cross sections (B-B', C-C', D-D', and G-G') have been improved with the addition of gamma-ray log traces, converted to digital images, and made accessible on the Web.

  17. Exploration applications of satellite imagery in mature basins - A summation

    SciTech Connect

    Berger, Z. )

    1991-08-01

    A series of examples supported by surface and subsurface controls illustrates procedures used to integrate satellite imagery interpretation into a conventional exploration program, and the potential contribution of such an approach to the recognition of new hydrocarbon plays in mature basins. Integrated analysis of satellite imagery data consists of four major steps. The first step focuses on the recognition of style, trend, and timing of deformation of exposed structures located at the basin interior or around its margins. This information is obtained through an integrated analysis of satellite imagery data, stereo aerial photography, surface geological mapping, and field observations. The second step consists of integrating the satellite imagery with gravity and magnetic data to recognize obscured and/or buried structures. The third step involves the analysis of available seismic data which is specifically processes to enhance subtle basement topography in order to determine influences on reservoir quality. In the fourth step, subsurface structure, isopach, show, and pool maps derived from available well information are integrated into the structural interpretation. These four analytical steps are demonstrated with examples form the Powder River basin, Western Canada basin, Paris basin, and Central basin platform of west Texas. In all of these highly mature basins, it is easy to demonstrate that (1) hydrocarbon migration and accumulation was largely controlled by subtle basement structures, and (2) these structures can be detected through the integrated analysis of satellite imagery.

  18. Carbon and sulfur relationships in Devonian shales from the Appalachian Basin as an indicator of environment of deposition.

    USGS Publications Warehouse

    Leventhal, J.S.

    1987-01-01

    Interprets the covariance of organic carbon and sulfide sulfur in core samples. This covariance results from the catabolism of organic carbon and concomitant reduction of sulfate by sulfate reducing bacteria to form aqueous sulfide which reacts with iron. Defines a central basin area that was the most anoxic-sulfidic (euxinic). This part of the basin is similar to the area of thickest, most organic carbon-rich sediments and has the greatest source-rock potential for petroleum. -from Author

  19. Zircon and apatite fission-track evidence for an Early Permian thermal peak and relatively rapid Late Permian cooling in the Appalachian Basin

    SciTech Connect

    Roden, M.K. . Dept. of Earth and Environmental Science); Wintsch, R.P. . Dept. of Geological Sciences)

    1992-01-01

    New zircon fission-track ages compliment published apatite fission-track ages in the Appalachian Basin to narrowly constrain its thermal history. Geologic evidence can only constrain timing of the thermal peak to be younger than late Pennsylvanian sediments ([approximately] 300 Ma) and older than Mesozoic sediments in the Newark and Gettysburg Basins ([approximately] 210 Ma). Apatite fission-track ages as old as 246 Ma require the Alleghanian thermal peak to have been pre-Triassic. Preliminary data on reset zircon fission-track ages from middle Paleozoic sediments range from 255 to 290 Ma. Zircon fission-track apparent ages from samples younger and structurally higher than these are not reset. Thus, the oldest reset zircon fission-track age constraints the time of the Alleghanian thermal peak to be earliest Permian. Rates of post-Alleghanian cooling have not been well-constrained by geologic data and could be very slow. The difference between apatite and zircon fission-track ages for most of the samples range from 100--120 m.y. reflecting Permo-Triassic cooling of only 1 C/m.y. However, one sample with one of the oldest apatite ages, 245 Ma, yields one of the younger zircon ages of 255 Ma. This requires cooling rates of 10 C/m.y. and uplift rates of [approximately] 0.5 mm/yr. Collectively, these data support an early Permian thermal peak and a two-stage cooling history, consisting of > 100 C cooling (> 8 km denundation) in the Permian followed by relatively slow cooling and exhumation throughout the Mesozoic.

  20. Trace-element budgets in the Ohio/Sunbury shales of Kentucky: Constraints on ocean circulation and primary productivity in the Devonian-Mississippian Appalachian Basin

    USGS Publications Warehouse

    Perkins, R.B.; Piper, D.Z.; Mason, C.E.

    2008-01-01

    The hydrography of the Appalachian Basin in late Devonian-early Mississippian time is modeled based on the geochemistry of black shales and constrained by others' paleogeographic reconstructions. The model supports a robust exchange of basin bottom water with the open ocean, with residence times of less than forty years during deposition of the Cleveland Shale Member of the Ohio Shale. This is counter to previous interpretations of these carbon-rich units having accumulated under a stratified and stagnant water column, i.e., with a strongly restricted bottom bottom-water circulation. A robust circulation of bottom waters is further consistent with the palaeoclimatology, whereby eastern trade-winds drove upwelling and arid conditions limited terrestrial inputs of siliciclastic sediment, fresh waters, and riverine nutrients. The model suggests that primary productivity was high (~ 2??g C m- 2 d- 1), although no higher than in select locations in the ocean today. The flux of organic carbon settling through the water column and its deposition on the sea floor was similar to fluxes found in modern marine environments. Calculations based on the average accumulation rate of the marine fraction of Ni suggest the flux of organic carbon settling out of the water column was approximately 9% of primary productivity, versus an accumulation rate (burial) of organic carbon of 0.5% of primary productivity. Trace-element ratios of V:Mo and Cr:Mo in the marine sediment fraction indicate that bottom waters shifted from predominantly anoxic (sulfate reducing) during deposition of the Huron Shale Member of the Ohio Shale to predominantly suboxic (nitrate reducing) during deposition of the Cleveland Shale Member and the Sunbury Shale, but with anoxic conditions occurring intermittently throughout this period. ?? 2008 Elsevier B.V.

  1. An Integrated Geochemical and Paleontological Investigation of Environmental and Biotic Change Associated with Late Devonian Mass Extinctions in the Appalachian Basin, USA

    NASA Astrophysics Data System (ADS)

    Haddad, E.; Love, G. D.; Boyer, D.; Droser, M. L.

    2012-12-01

    The Upper Kellwasser (uK) black shale, a global unit at the Frasnian-Famennian boundary, closely associated with the Late Devonian extinction event, is commonly linked to oxygen limitation in the water column. In spite of the significance of this time interval, the nature of the ocean redox geochemistry is poorly understood. Using a multi-proxy approach, this study tests the appropriateness of three distinct oceanographic models for ocean redox chemistry at this time: 1) an oxic setting with sub-oxic bottom waters but with sulfide production confined to sedimentary porewaters; 2) an expanded oxygen minimum zone within a highly stratified marine redox column with only intermittent photic zone (shallow water) euxinia; and 3) a persistently euxinic water column extending up into the photic zone. Bottom water oxygen conditions are described at a high resolution for 4 uK black shale localities in western New York State, using inorganic and organic geochemical proxies and trace fossils to constrain relative oxygen levels and identify signals of anoxia and euxinia in the Devonian Appalachian Basin. Mo concentrations typically range from crustal (2-3 ppm) to moderately enriched values suggestive of suboxic conditions (typically less than 30 ppm), with some higher values between 30 and 40 ppm perhaps suggesting intermittent euxinia, indicating that the uK black shale preserves reduced oxygen bottom water conditions. The levels of enrichment are muted, though, such that these are inconsistent with persistent anoxia or euxinia for the interval, especially as compared to other Phanerozoic euxinic black shale intervals. Other trace metals suggest similarly suboxic to intermittently anoxic bottom water conditions. Lipid biomarker patterns are typical for Paleozoic marine rocks, indicating that the biomarker molecules in the extracted bitumens are syndepositional and not significantly affected by contamination. Independent thermal maturity screening data indicating peak oil

  2. Thermal maturity patterns in Pennsylvanian coal-bearing rocks in Alabama, Tennessee, Kentucky, Virginia, West Virginia, Ohio, Maryland, and Pennsylvania: Chapter F.2 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ruppert, Leslie F.; Trippi, Michael H.; Hower, James C.; Grady, William C.; Levine, Jeffrey R.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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

  3. William Maclure's Wernerian Appalachians

    USGS Publications Warehouse

    Lessing, P.

    1999-01-01

    William Maclure (1763-1840), a geologist of Scottish ancestry, was also a man of many other talents and interests including educator, philanthropist, world traveler, prolific writer, patron of science, businessman, bibliophile, and social reformer. He produced the first American printing of a geological map of the United States in 1809 and followed this with four other editions identified as 1811, 1817A, 1817B, and 1817C. All were well received and reproduced by others at least 15 times, as recently as 1989. Maclure has been called 'Father of American Geology,' a title he rightly deserves, primarily for these maps, but also for the first cross sections through the Appalachians, many other geological articles, and substantial donations of specimens, books, and funds to many learned institutions, including the Academy of Natural Sciences of Philadelphia. Maclure's delineation of Appalachian geology followed Werner's geognostic classification of strata using Primary, Transition, Secondary, and Alluvial, but with modifications and considerable doubt concerning their Neptunian origin. He added 'Rock Salt' on his 1809 map as a line on the western edge of the Appalachians and 'Old Red Sand Stone' on the 1811 map for the basins later identified as Triassic. In his later articles, Maclure noted several times that 'trap' or basalt was an igneous rock and not an aqueous precipitate. He further stated that the Secondary and Transition strata are aggregates from the disintegration of the older Primitive rocks. He came to the conclusion near the end of his life that organic remains indicate '...that nature began with the most simple, and gradually proceeded to the more complicated and perfect.'.

  4. Exploration for coalbed methane gains momentum in Uinta basin

    USGS Publications Warehouse

    Gloyn, Robert W.; Sommer, Steven N.

    1993-01-01

    A development program is planned, and at least three other companies are exploring for coalbed methane in the surrounding area. Estimates have been revised by the Utah Geological Survey for the coalbed methane potential of the southern Uinta basin. They are 8 tcf to more than the earlier estimates of 0.8-4.6 tcf.

  5. Integration of photomosaics and stratigraphy in the Western Appalachian Basin as an aid to identify potential hydrocarbon reservoirs

    SciTech Connect

    Wegweiser, M.D.

    1996-09-01

    Paleozoic stratigraphy of the southern Lake Erie region is commonly interpreted as being dominated by flat-lying sedimentary rocks. Recent surface stratigraphic studies in New York, Pennsylvania, and Ohio have revealed the widespread presence of NW- and NE-trending folds and faults exposed along stream beds, and in bluffs along the southern Lake Erie shoreline. A black shale unit, previously unknown in northwestern Pennsylvania, was also discovered and its lateral continuity mapped. The shale forms a disconformable contact with the overlying Northeast Shale. Ship-based photomosaics were made of bluffs along Lake Erie, and integrated with land-based stratigraphic sections to map the continuity of units, identify displacement zones, and identify low amplitude folds. The black shale unit aided identification of offset and folding. Faults observed at the surface off-set Devonian and Mississippian rocks, and unconsolidated Quaternary sediments. Subsurface wrench faults, apparently extending into Precambrian rocks, have been identified by others. These wrench faults are generally perpendicular to the strike of the Appalachian Mountains, and are known as cross-strike discontinuities (CSDs). Principle zones of displacement associated with the CSDs can be recognized at the surface by numerous fractures having little offset, aligned drainage systems, and zones of increased hydrocarbon productivity and fluid migration. Increased hydrocarbons production occurs where reservoirs are cross-cut by the faults. The faults offset various reservoirs in Pennsylvania and Ohio in the subsurface. Identifying the location of these faults at the surface may provide information that leads top the discovery of new potential reservoirs.

  6. Integrated exploration study of Norwegian-Danish basin, northwestern Europe

    SciTech Connect

    Joergensen, N.B.; Haselton, T.M.

    1987-05-01

    The Norwegian-Danish basin (NDB) extends from offshore Norway southeast through Denmark. This study, initiated by the Danish Energy Agency to evaluate hydrocarbon potential, consists of geophysical structural and stratigraphic mapping combined with geologic source rock and reservoir analysis. Approximately 25 wells and 15,000 km of seismic data were included. Formation of the NDB resulted from uplift of the Variscan foldbelt followed by subsidence of the foreland, i.e., the NDB and the North German basin. The Ringkoebing-Fyn High, a positive feature probably established in the late Precambrian and persisting to present, separates the basins, thus constituting the southern boundary of the NDB. Northeast the basin is bounded by the Fennoscandian shield and to the west by the North Sea graben system. Following deposition of Rotliegendes eolian and fluviatile sandstones, a major Late Permian marine transgression deposited up to 2000 m of evaporites and carbonates. Early Triassic regression resulted in thick red-bed deposits. Halokinesis commencing in the Upper Triassic dominated subsequent structural development. Continued subsidence led to deposition of Early Jurassic shelf mudstones overlain by deltaic sandstones. Rising seas during Late Cretaceous allowed widespread deposition of oceanic pelagic chalk. Early Paleocene wrench movements produced inversion. Basinal downwarping during the Tertiary was accompanied by progradation from the northeast. The complex tectonic history provides numerous different structural styles and a variety of depositional environments. To date only obvious structural features have been tested. This integrated basin study demonstrates that a number of other hydrocarbon plays remain to be explored.

  7. Geologic cross section C-C' through the Appalachian basin from Erie County, north-central Ohio, to the Valley and Ridge province, Bedford County, south-central Pennsylvania

    USGS Publications Warehouse

    Ryder, Robert T.; Trippi, Michael H.; Swezey, Christopher S.; Crangle, Robert D.; Hope, Rebecca S.; Rowan, Elisabeth L.; Lentz, Erika E.

    2012-01-01

    Geologic cross section C-C' is the third in a series of cross sections constructed by the U.S. Geological Survey (USGS) to document and improve understanding of the geologic framework and petroleum systems of the Appalachian basin. Cross section C-C' provides a regional view of the structural and stratigraphic framework of the Appalachian basin from north-central Ohio to the Valley and Ridge province in south-central Pennsylvania, a distance of approximately 260 miles (mi). This cross section is a companion to cross sections E-E' and D-D' that are located about 50 to 125 mi and 25 to 50 mi, respectively, to the southwest. Cross section C-C' contains much information that is useful for evaluating energy resources in the Appalachian basin. Although specific petroleum systems are not identified on the cross section, many of their key elements (such as source rocks, reservoir rocks, seals, and traps) can be inferred from lithologic units, unconformities, and geologic structures shown on the cross section. Other aspects of petroleum systems (such as the timing of petroleum generation and preferred migration pathways) may be evaluated by burial history, thermal history, and fluid flow models based on what is shown on the cross section. Cross section C-C' also provides a general framework (stratigraphic units and general rock types) for the coal-bearing section, although the cross section lacks the detail to illustrate key elements of coal systems (such as paleoclimate, coal quality, and coal rank). In addition, cross section C-C' may be used as a reconnaissance tool to identify plausible geologic structures and strata for the subsurface storage of liquid waste or for the sequestration of carbon dioxide.

  8. Stratigraphic Framework and Depositional Sequences in the Lower Silurian Regional Oil and Gas Accumulation, Appalachian Basin: From Licking County, Ohio, to Fayette County, West Virginia

    USGS Publications Warehouse

    Ryder, Robert T.

    2006-01-01

    The Lower Silurian regional oil and gas accumulation was named by Ryder and Zagorski (2003) for a 400-mile (mi)-long by 200-mi-wide hydrocarbon accumulation in the central Appalachian basin of the Eastern United States and Ontario, Canada. From the early 1880s to 2000, approximately 300 to 400 million barrels of oil and eight to nine trillion cubic feet of gas have been produced from the Lower Silurian regional oil and gas accumulation (Miller, 1975; McCormac and others, 1996; Harper and others, 1999). Dominant reservoirs in the regional accumulation are the Lower Silurian 'Clinton' and Medina sandstones in Ohio and westernmost West Virginia and coeval rocks in the Lower Silurian Medina Group (Grimsby Sandstone (Formation) and Whirlpool Sandstone) in northwestern Pennsylvania and western New York. A secondary reservoir is the Upper Ordovician(?) and Lower Silurian Tuscarora Sandstone in central Pennsylvania and central West Virginia, a more proximal eastern facies of the 'Clinton' sandstone and Medina Group (Yeakel, 1962; Cotter, 1982, 1983; Castle, 1998). The Lower Silurian regional oil and gas accumulation is subdivided by Ryder and Zagorski (2003) into the following three parts: (1) an easternmost part consisting of local gas-bearing sandstone units in the Tuscarora Sandstone that is included with the basin-center accumulation; (2) an eastern part consisting predominantly of gas-bearing 'Clinton' sandstone-Medina Group sandstones that have many characteristics of a basin-center accumulation (Davis, 1984; Zagorski, 1988, 1991; Law and Spencer, 1993); and (3) a western part consisting of oil- and gas-bearing 'Clinton' sandstone-Medina Group sandstones that is a conventional accumulation with hybrid features of a basin-center accumulation (Zagorski, 1999). With the notable exception of the offshore part of Lake Erie (de Witt, 1993), the supply of oil and (or) gas in the hybrid-conventional part of the regional accumulation continues to decline because of the many

  9. Identifying Seismic Risk in the Appalachian Basin Geothermal Play Fairway Analysis Project Using Potential Fields, Seismicity, and the World Stress Map

    NASA Astrophysics Data System (ADS)

    Horowitz, F. G.

    2015-12-01

    A collaborative effort between Cornell University, Southern Methodist University, and West Virginia University has been sponsored by the US Department Of Energy to perform a Geothermal Play Fairway Analysis of the low temperature direct use potential for portions of the Appalachian sedimentary basin in New York, Pennsylvania and West Virginia - abbreviated here as GPFA-AB. One risk factor - of several being analyzed for the GPFA-AB - is whether a candidate location is near an active fault, and thereby potentially susceptible to induced seismicity from geothermal operations. Existing fault maps do not share the GPFA-AB boundaries or scale. Hence, their use leads to problems of uneven coverage, varying interpretation of faults vs. lineaments, and different mapping scales. For more uniformity across the GPFA-AB region, we use an analysis of gravity and magnetic fields. Multiscale edge Poisson wavelet analyses of potential fields ("worms") have a physical interpretation as the locations of lateral boundaries in a source distribution that exactly generates the observed field. Not all worms are faults, and of faults, only a subset might be active. Also, worms are only sensitive to steeply dipping structures. To identify some active structures, we plot worms and intra-plate earthquakes from the ISC, NEIC, and EarthScope TA catalogs. Worms within a small distance of epicenters are tracked spatially. To within errors in location, this is a sufficient condition to identify structures that might be active faults - which we categorize with higher risk than other structures. Plotting worms within World Stress Map σ1 directions yields an alternative approach to identifying activatable structures. Here, we use worms to identify structures with strikes favorably oriented for failure by Byerlee's law. While this is a necessary criterion for fault activation it is not a sufficient one - because we lack detailed information about stress magnitudes throughout the GPFA-AB region

  10. Detrital mica K/Ar ages for Devonian-Pennsylvanian strata of the north central Appalachian Basin: Dominance of the Acadian Orogen as provenance

    SciTech Connect

    Aronson, J.L. . Dept. of Geological Sciences); Lewis, T.L. . Dept. of Geological Sciences)

    1992-01-01

    Detrital micas were separated from: the Upper Devonian Walton Sandstone and Ohio Shale; Lower Mississippian Berea Sandstone; Upper Mississippian Mauch Chunk Formation; and the Lower-Middle Pennsylvanian Pottsville and Allegheny Sandstones. A total of 12 separates were conventionally dated, the only biotite being from the Allegheny Formation sandstone, from which a muscovite was also dated. The total range in dates for the study was encompassed by the Allegheny sample of 414 m.y. (muscovite) to 361 m.y. (biotite), each date having an uncertainty of about [+-] 9 m.y. Excluding this sample, a narrower range of Early to Middle Devonian dates from 406--371 m.y. is obtained. For the Walton Sandstone of the proximal Catskill Wedge and for the northeast OH samples of the distal Catskill Wedge, all deposited within Late Devonian-Early Mississippian time, a very narrow span of 20 m.y. is obtained entirely within Early Devonian time and only approximately 30 m.y. older than deposition. All of these provenance ages have been previously found as primary ages of crystallization or cooling therefrom of regional metamorphism and plutonism in the Acadian Orogen of New England. The mean provenance ages are so close to the age of deposition of the distal Devonian/mississippian Catskill strata as to preclude almost any Precambrian contribution from either the Canadian Shield or the uplifted cores of the Orogen. These results support the paleocurrent and paleoenvironmental analysis of the northeast OH section by Lewis (1988) and argue against the classic Bedford Delta interpretation sourced from the north. Furthermore, the Acadian Orogen persisted as the major provenance for the clastic pulses that prograded into the central Appalachian Basin after the post-Catskill transgression, at least up until Middle Pennsylvanian time.

  11. Early and Late Diagenetic Origins of the widespread middle Devonian Purcell/Cherry Valley Limestone in the Appalachian Basin

    NASA Astrophysics Data System (ADS)

    Wang, J.; Arthur, M. A.

    2013-12-01

    Isotopic geochemistry, lithofacies characteristics and fluid inclusion microthemometry are investigated to evaluate the deposition and diagenesis of the thin, basin-wide Purcell/Cherry Valley carbonate member within the Middle Devonian Marcellus Formation. This carbonate interval is fine-grained and sparsely fossiliferous, with abundant nodular and disseminated pyrite, which distinguish it from normal lowstand carbonate units. A process that involves upward or lateral migration of methane with oxidation at or near the seafloor by sulfate-reduction, precipitating pyrite and 13C-depleted carbonate (commonly less than -10‰) could be responsible for the origin of this unusual carbonate layer. Samples of Purcell/Cherry Valley carbonate within Marcellus black shale collected from both shallow well core from the basin margin and core from producing wells in the basin center exhibit depleted carbon isotopic (δ13C=-10.2 to -2‰) and highly depleted oxygen isotopic signatures (δ18O=-13.2 to -8.7‰). The oxygen isotope values may indicate strong late diagenetic overprint. Primary fluid inclusions in calcite precipitates within tectonically induced fractures in this carbonate member mainly consist of three different types: aqueous brine inclusions, methane inclusions and light hydrocarbon inclusions. The petrologic analysis of fluid inclusions shows that hydrocarbons migrated with the brine. The homogenization temperatures of fluid inclusions suggest mineral trapping occurred at fluid temperatures of 90-98°C. Moreover, with constrains of isotopic composition of Devonian oilfield brine (δ18O =+2 to -3‰) and veins (δ18O=-12 to -11‰, δ13C=-3.0 to 1‰), the calculated diagenetic temperature should also be relatively high (~ 100°C). Lithofacies characteristics, isotopic compositions and fluid inclusion microthermometries are all consistent with the conclusion that this carbonate member partially originated from methane oxidation and then underwent a high degree of

  12. Evaluation of the hydrocarbon source-rock potential of carbonaceous shales; Upper Devonian shales of the Appalachian Basin

    SciTech Connect

    Curtis, J.B. Jr.

    1989-01-01

    This study investigated the organic matter contained in the Lower Huron Member of the Ohio Shale Formation and the Rhinestreet Shale Member of the West Falls Formation (Devonian) in Kentucky, Ohio, West Virginia, and Virginia. The organic matter in these formations is predominantly marine in origin, and was most probably derived from algal organisms. The preservation of the organic matter was apparently controlled by the existence of a set of fault-bounded basins associated with the Rome Trough. These basins were anoxic because of limited oxygen recharge by circulating waters. Preservation of organic matter was also enhanced by periodic blooms of the alga Tasnmanites and similar organisms in the waters above the local basins during both Lower Huron and Rhinestreet times. These blooms created such large concentrations of organic matter that the supply of molecular oxygen was exhausted and the preservation of the algal material was enhanced. The temperature dose measured by the reflectance of vitrinite particles was corrected for depth effects in order to identify areas where the rocks had been heated in excess of the normal geothermal gradient. Corrected Vitrinite Temperatures were used to identify those areas where more localized heat pulses have occurred. These heat pulses may have been caused by hot brines circulating from depth through fractures in the affected rocks. The enhanced permeability of the fractures results in anomalously high, present-day heat flow values, and production of hydrocarbon liquids. A significant negative correlation was identified between the vitrinite reflectance temperature, an integrated measure of the thermal history of a rock, and the hydrogen index, a measure of the remaining hydrocarbon potential of kerogen.

  13. Tamarugal basin exploration under way in northern Chile

    SciTech Connect

    Roos, M.

    1996-12-30

    The government of Chile has awarded an exploration contract to Cardinal Resources Inc., headquartered in White Plains, N.Y., to develop oil and natural gas for commercial production on a large inland tract in northern Chile. Recent geological/geophysical evaluations of the contract area by both Cardinal and Empresa Nacional del Petroleol (ENAP), the state energy company, have upgraded the hydrocarbon potential of this northern basin, making it an attractive exploration play. The paper describes the contract area, two oil seeps that have been discovered, structural history, Jurassic stratigraphy, and interpretation of the aeromagnetic and Landsat data.

  14. Petroleum geology and exploration of Tarim Basin, China

    SciTech Connect

    Liang Di-Gang; Jia Cheng-Zao

    1996-12-31

    Since 1989 CNPC has carried on large-scale oil and gas exploration and geological research in Tarim Basin of Xinjiang Province, China. Twelve thousand km 2D seismic, 4500 km{sup 2} 3D seismic, and 200 exploratory wells have been completed; ninety-five wells yield commercial oil or gas flows. At this time, eight oil/gas fields have been discovered; they include Lunnan, Yaha, and Tazhong No. 4, having proved 2.7x10{sup 8}t of oil and 109.2x10{sup 9}m{sup 3} of gas in place. Two million six hundred thousand tons of crude oil was yielded in 1995 and 5x10{sup 8}t crude oil will be produced in 1997. The facies of discovered oil-gas pools in Tarim Basin are complex: there are condensate gas pools, volatile oil pools, normal oil pools, and some heavy oil pools. Structural traps form 80% of oil-gas pools. Oil-gases are mainly reservoired in sandstone beds. The burial depths of oil-gas pools range mainly from 4000 to 5500m. Oil and condensate gas occupy 60% and 40% of proved reserves respectively. Oil-gas pools are mainly distributed in the Mesozoic-Cenozoic group, in which Tertiary occupies 50%, Triassic occupies 30% and Carboniferous occupies 20%. Tarim Basin is a large overlapped composite basin, composed of Paleozoic cratonic basins and Mesozoic-Cenozoic foreland basins. Paleozoic and Mesozoic-Cenozoic oil-gas pools have different distribution character. Paleozoic oil-gas accumulations are controlled by cratonic paleo-uplifts and slopes. Mesozoic-Cenozoic oil-gas accumulations are controlled by foredeep uplifts and imbricate thrust structures of foreland thrust belts.

  15. Petroleum geology and exploration of Tarim Basin, China

    SciTech Connect

    Liang Di-Gang; Jia Cheng-Zao )

    1996-01-01

    Since 1989 CNPC has carried on large-scale oil and gas exploration and geological research in Tarim Basin of Xinjiang Province, China. Twelve thousand km 2D seismic, 4500 km[sup 2] 3D seismic, and 200 exploratory wells have been completed; ninety-five wells yield commercial oil or gas flows. At this time, eight oil/gas fields have been discovered; they include Lunnan, Yaha, and Tazhong No. 4, having proved 2.7x10[sup 8]t of oil and 109.2x10[sup 9]m[sup 3] of gas in place. Two million six hundred thousand tons of crude oil was yielded in 1995 and 5x10[sup 8]t crude oil will be produced in 1997. The facies of discovered oil-gas pools in Tarim Basin are complex: there are condensate gas pools, volatile oil pools, normal oil pools, and some heavy oil pools. Structural traps form 80% of oil-gas pools. Oil-gases are mainly reservoired in sandstone beds. The burial depths of oil-gas pools range mainly from 4000 to 5500m. Oil and condensate gas occupy 60% and 40% of proved reserves respectively. Oil-gas pools are mainly distributed in the Mesozoic-Cenozoic group, in which Tertiary occupies 50%, Triassic occupies 30% and Carboniferous occupies 20%. Tarim Basin is a large overlapped composite basin, composed of Paleozoic cratonic basins and Mesozoic-Cenozoic foreland basins. Paleozoic and Mesozoic-Cenozoic oil-gas pools have different distribution character. Paleozoic oil-gas accumulations are controlled by cratonic paleo-uplifts and slopes. Mesozoic-Cenozoic oil-gas accumulations are controlled by foredeep uplifts and imbricate thrust structures of foreland thrust belts.

  16. Record of glacial-eustatic sea-level fluctuations in complex middle to late Pennsylvanian facies in the Northern Appalachian Basin and relation to similar events in the Midcontinent basin

    NASA Astrophysics Data System (ADS)

    Belt, Edward S.; Heckel, Philip H.; Lentz, Leonard J.; Bragonier, William A.; Lyons, Timothy W.

    2011-06-01

    Pennsylvanian cycles in the Northern Appalachian Basin (NAB) were historically considered to result from delta-lobe switching, and more recently from sea-level fluctuation with sandy deltas prograding during highstand. These interpretations are revised using new data from cores and outcrop exposures. Thick (> 5 m) channel deposits with a marked erosion surface at their base cutting down across previous cycles are re-interpreted as incised valley fill (IVF) deposits in paleovalleys, because the basal erosion surfaces are widespread, and thus reflect a record of lowstand. Most common are simple paleovalleys that contain mainly sandy fluvial deposits. Compound paleovalleys with sequence boundaries above the basal erosion surface, contain terrestrial, estuarine, and marine deposits. Early to late highstand deposits in interfluvial parts of the cycles are dominated by shale and mudstone, with paleosols, coals, and local non-marine limestone, which reflect floodbasin to lacustrine conditions. These reinterpretations are applied to previously and newly recognized cycles in ascending order: Upper Kittanning, Lower Freeport, Upper Freeport Leader (new), Upper Freeport, Piedmont (new), Mahoning, Mason interval (locally includes Upper New Galilee in the north), and Brush Creek, across a 300-km arc in the Northern Appalachian Basin. These deposits accumulated in a 'high shelf' setting that experienced fewer marine transgressions, and were interrupted by more frequent exposure and downcutting, in contrast to the thicker and more complete succession with more numerous marine units in the Midcontinent. Magnitudes of highstand transgressions into this basin, deduced from the up-dip extent of marine and brackish fossil assemblages, were greatest for the Brush Creek, less so for the Upper Kittanning and Mahoning, and least for the Lower Freeport, Upper Freeport Leader, Piedmont, and Mason. The anomalous basin-wide fresh-water roofshales and equivalents of the Upper Freeport coal may

  17. Thrust-ridge paleodepositional model for the Upper Freeport coal bed and associated clastic facies, Upper Potomac coal field, Appalachian Basin, U.S.A.

    USGS Publications Warehouse

    Belt, E.S.; Lyons, P.C.

    1990-01-01

    developed from one of the outboard ridges, and it was thrust farther outboard ahead of the main body of the orogen. Sediment derived from the orogen was diverted into a sediment trap inboard of the ridge (Fig. 1). The ridge prevented sediment from entering the main peat-forming swamp. Sediment shed from the orogen accumulated in the sediment trap was carried out of the ends of the trap by steams that occupied the shear zone at the ends of the blind-thrust ridge (Fig. 1). Remnants of blind-thrust ridges occurs in the Sequatchie Valley thrust and the Pine Mountain thrust of the southern Appalachians. The extent, parallel to the orogen, of the thick areally extensive UF coal is related to the length of the blind-thrust ridge that, in turn, controlled the spacing of the river-derived coarse clastics that entered the main basin from the east. Further tectonism caused the thrust plane to emerge to the surface of the blind-thrust ridge. Peat accumulation was then terminated by the rapid erosion of the blind-thrust ridge and by the release of trapped sediment behind it. The peat was buried by sediments from streams from closely spaced channel belts] with intervening floodbasins. The model was implications for widespread peat (coal) deposits that developed in tropical regions, a few hundred kilometers inland from the sea during Pennsylvanian time (Belt and Lyons, 1989). ?? 1990.

  18. New exploration targets in Malaysia: Deep sandstone reservoirs in Malay basin and turbidites in Sabah basin

    SciTech Connect

    Ngah, K.B. )

    1996-01-01

    Much of the production in Malaysia is from middle to upper Miocene sandstones and carbonates in three main basins: Malay, Sarawak (Its three subbasins-Central Luconia, Balingian and Baram), and Sabah. Fifteen fields produce an average of 630,000 bopd and 3.0 bcfgpd. More than 4.0 billion barrels of oil and 20 tcf of gas have been produced, and reserves are 4.2 billion barrels of oil and 90 tcf. Oil production will decline within the next 1 0 years unless new discoveries are made and/or improved oil recovery methods introduced, but gas production of 5 tcf, expected after the turn of the century, can be sustained for several decades. Successful exploratory wells continue to be drilled in the Malaysian Tertiary basins, and others are anticipated with application of new ideas and technology. In the Malay basin, Miocene sandstone reservoirs in Groups L and M have been considered as very [open quote]high risk[close quotes] targets, the quality of the reservoirs has generally been thought to be poor, especially toward the basinal center, where they occur at greater depth. The cause of porosity loss is primarily burial-related. Because of this factor and overpressuring, drilling of many exploration wells has been suspended at or near the top of Group L. In a recent prospect drilled near the basinal axis on the basis of advanced seismic technology, Groups L and M sandstones show fair porosity (8-15%) and contain gas. In the Sabah basin, turbidite play has received little attention, partly because of generally poor seismic resolution in a very complex structural setting. Only one field is known to produce oil from middle Miocene turbidities. However, using recently acquired 3-D seismic data over this field, new oil pools have been discovered, and they are currently being developed. These finds have created new interest, as has Shell's recent major gas discovery from a turbidite play in this basin.

  19. New exploration targets in Malaysia: Deep sandstone reservoirs in Malay basin and turbidites in Sabah basin

    SciTech Connect

    Ngah, K.B.

    1996-12-31

    Much of the production in Malaysia is from middle to upper Miocene sandstones and carbonates in three main basins: Malay, Sarawak (Its three subbasins-Central Luconia, Balingian and Baram), and Sabah. Fifteen fields produce an average of 630,000 bopd and 3.0 bcfgpd. More than 4.0 billion barrels of oil and 20 tcf of gas have been produced, and reserves are 4.2 billion barrels of oil and 90 tcf. Oil production will decline within the next 1 0 years unless new discoveries are made and/or improved oil recovery methods introduced, but gas production of 5 tcf, expected after the turn of the century, can be sustained for several decades. Successful exploratory wells continue to be drilled in the Malaysian Tertiary basins, and others are anticipated with application of new ideas and technology. In the Malay basin, Miocene sandstone reservoirs in Groups L and M have been considered as very {open_quote}high risk{close_quotes} targets, the quality of the reservoirs has generally been thought to be poor, especially toward the basinal center, where they occur at greater depth. The cause of porosity loss is primarily burial-related. Because of this factor and overpressuring, drilling of many exploration wells has been suspended at or near the top of Group L. In a recent prospect drilled near the basinal axis on the basis of advanced seismic technology, Groups L and M sandstones show fair porosity (8-15%) and contain gas. In the Sabah basin, turbidite play has received little attention, partly because of generally poor seismic resolution in a very complex structural setting. Only one field is known to produce oil from middle Miocene turbidities. However, using recently acquired 3-D seismic data over this field, new oil pools have been discovered, and they are currently being developed. These finds have created new interest, as has Shell`s recent major gas discovery from a turbidite play in this basin.

  20. REGIONAL MAGNETOTELLURIC SURVEYS IN HYDROCARBON EXPLORATION, PARANA BASIN, BRAZIL.

    USGS Publications Warehouse

    Stanley, William D.; Saad, Antonio; Ohofugi, Walter

    1985-01-01

    The mangetotelluric geophysical method has been used effectively as a hydrocarbon exploration tool in the intracratonic Parana basin of South America. The 1-2 km thick surface basalts and buried diabase sills pose no problem for the magnetotelluric method because the natural electromagnetic fields used as the energy source pass easily through the basalt. Data for the regional study were taken on six profiles with sounding spaced 8 to 15 km apart. The magnetotelluric sounding data outline a linear uplift known as the Ponta Grossa arch. This major structural feature cuts across the northeast-trending intracratonic basin almost perpendicularly, and is injected with numerous diabase dikes. Significant electrical contrasts occur between the Permian sediments and older units, so that magnetotelluric measurements can give an indication of the regional thickness of the Permian and younger sediments to aid in interpreting hydrocarbon migration patterns and possible trap areas. Refs.

  1. Thermal maturity patterns (CAI and %R) in the Ordovician and Devonian rocks of the Appalachian basin in Pennsylvania

    USGS Publications Warehouse

    Repetski, John E.; Ryder, Robert T.; Harper, John A.; Trippi, Michael H.

    2002-01-01

    The objective of this study is to enhance existing thermal maturity maps in Pennsylvania by establishing: 1) new subsurface CAI data points for the Ordovician and Devonian and 2) new %Ro and Rock Eval subsurface data points for Middle and Upper Devonian black shale units. Thermal maturity values for the Ordovician and Devonian strata are of major interest because they contain the source rocks for most of the oil and natural gas resources in the basin. Thermal maturity patterns of the Middle Ordovician Trenton Group are evaluated here because they closely approximate those of the overlying Ordovician Utica Shale that is believed to be the source rock for the regional oil and gas accumulation in Lower Silurian sandstones (Ryder and others, 1998) and for natural gas fields in fractured dolomite reservoirs of the Ordovician Black River-Trenton Limestones. Improved CAI-based thermal maturity maps of the Ordovician are important to identify areas of optimum gas generation from the Utica Shale and to provide constraints for interpreting the origin of oil and gas in the Lower Silurian regional accumulation and Ordovician Black River-Trenton fields. Thermal maturity maps of the Devonian will better constrain burial history-petroleum generation models of the Utica Shale, as well as place limitations on the origin of regional oil and gas accumulations in Upper Devonian sandstone and Middle to Upper Devonian black shale.

  2. Thermal maturity patterns (CAI and %Ro) in the Ordovician and Devonian rocks of the Appalachian basin in West Virginia

    USGS Publications Warehouse

    Repetski, John E.; Ryder, Robert T.; Avary, Katharine Lee; Trippi, Michael H.

    2005-01-01

    The objective of this study is to enhance existing thermal maturity maps in West Virginia by establishing: 1) new subsurface CAI data points for the Ordovician and Devonian and 2) new %Ro and Rock Eval subsurface data points for Middle and Upper Devonian black shale units. Thermal maturity values for the Ordovician and Devonian strata are of major interest because they contain the source rocks for most of the oil and natural gas resources in the basin. Thermal maturity patterns of the Middle Ordovician Trenton Limestone are evaluated here because they closely approximate those of the overlying Ordovician Utica Shale that is believed to be the source rock for the regional oil and gas accumulation in Lower Silurian sandstones (Ryder and others, 1998) and for natural gas fields in fractured dolomite reservoirs of the Ordovician Black River-Trenton Limestones. Improved CAI-based thermal maturity maps of the Ordovician are important to identify areas of optimum gas generation from the Utica Shale and to provide constraints for interpreting the origin of oil and gas in the Lower Silurian regional accumulation and Ordovician Black River-Trenton fields. Thermal maturity maps of the Devonian will better constrain burial history-petroleum generation models of the Utica Shale, as well as place limitations on the origin of regional oil and gas accumulations in Upper Devonian sandstone and Middle to Upper Devonian black shale.

  3. Accumulation of organic matter in the in the Rome trough of the Appalachian basin and its subsequent thermal history

    SciTech Connect

    Curtis, J.B.; Faure, G.

    1997-03-01

    We used geochemical data to examine the origin and preservation of organic matter contained in the lower part of the Huron Member of the Ohio Shale formation and the Rhinestreet Shale Member of the West Falls Formation (Devonian) in Kentucky, Ohio, West Virginia, and Virginia. The thermal history of the organic matter was determined by relating relative temperatures experienced by the organic matter to the geologic setting. The organic matter in these formations is predominantly marine in origin and was most probably derived largely from algal organisms. Although the rate of production of marine organic matter may have been uniform within the basin, its preservation apparently was controlled by the existence of a set of fault-bounded anoxic subbasins associated with the Rome trough, a Cambrian structural complex. These subbasins apparently were anoxic because they limited oxygen recharge by circulating waters. Preservation of organic matter was also enhanced by periodic blooms of the alga Tasmanites and similar organisms in the waters above the subbasins during both early Huron and Rhinestreet deposition. A significant negative correlation was identified between the vitrinite reflectance peak temperature, and integrated measure of the thermal history of a rock, and the hydrogen index, a measure of the remaining hydrocarbon-generation potential of kerogen. Although peak temperatures were controlled by burial depth, excess heating occurred locally, perhaps by hot brines rising from depth through fractures associated with major structures in the study area.

  4. Russians to seek exploration in difficult Far East basins

    SciTech Connect

    1998-06-01

    Local governments and associations in Russia hope to encourage exploration interest in lightly explored, mostly nonproducing offshore basins in the Far East. Adjacent onshore areas have experienced recurring shortages of natural gas and petroleum products. Russian authorities have been attempting to license blocks in far eastern waters for much of the 1990s, but political, bureaucratic, fiscal, and tax uncertainties have frustrated most efforts. Approval of the Russian Parliament is needed for tender offers, and no one can predict when such approvals might be forthcoming. Dalwave is offering a package of more than 40,000 km of 24--48 fold regional 2D seismic data on nearly 400 lines in the Sea of Okhotsk and Bering Sea. The package is being made available to give geoscientists a head start at regional evaluation outside the Sakhalin Island area. The paper describes Russian`s Far East resources, exploration prospects, and other considerations.

  5. Recent developments of seismic exploration in the Tannwald basin

    NASA Astrophysics Data System (ADS)

    Burschil, Thomas; Buness, Hermann; Gabriel, Gerald

    2016-04-01

    The ICDP proposal DOVE (Drilling Overdeepened Alpine Valleys) intends to examine the Quaternary glacial cycles in the Alpine region. The sediment succession of overdeepened valleys and basins will be analysed in a multidisciplinary way. Other objectives are related to groundwater supply and geohazards in Alpine valleys. In the context of DOVE, a DFG-funded project studies the benefit of modern multi-component reflection seismics. This project intends to characterize the structure and facies of the sedimentary fillings and to transfer methodological results to the DOVE drill sites. In 2014 and 2015 several reflection seismic surveys were carried out in the Tannwald basin, located about 50 km NE of Lake Constance. The basin constitutes a relict of one of the Rhine Glacier lobes in the Pleistocene. In total, we acquired five high-resolution profiles using P-waves, two profiles using horizontally polarized shear waves, and one profile using multi-component technique (SV- and SH-wave source, 3-component receivers) to explore the sedimentary filling of the basin. The P-wave profiles generally show strong heterogeneity and variations in the reflection pattern. Distinct reflections in depths between 100 m and 200 m are identified as basement, i.e. top Molasse, which is supported by a nearby research borehole. In particular, a ramp-like structure is prominent over a distance of 450 m and dips about 10°. Internal structures of the basin filling form discontinuous reflection segments, which are only visible in parts of the profile. The SH-wave profiles resolve both internal structures in detail and the basement. Since the location of the SH-wave profiles coincides with P-wave profiles, a detailed comparison of the structures gained from P-wave and SH-wave seismic exploration is possible. Moreover, Vp/Vs and Poisson ratio are calculated from P- and S-wave velocities received from refraction seismic tomography and the stack velocities, respectively. Further steps are

  6. Multiple-bench architecture and interpretations of original mire phases - Examples from the Middle Pennyslvanian of the Central Appalachian Basin, USA

    USGS Publications Warehouse

    Greb, S.F.; Eble, C.F.; Hower, J.C.; Andrews, W.M.

    2002-01-01

    Coal seams often exhibit lateral and vertical variability in composition. When sampled as a whole seam this variability is masked. But if a seam is subdivided into correlateable components, this variability can be tested and better understood. Herein, an architectural approach is used to divide seams into intra-seam components. Clastic splits and mineral partings, as well as persistent fusain and durain layers, can be used as intra-seam bounding units to subdivide a seam into subdivisions called benches. Regional examination of Lower and Middle Pennsylvanian-age coal seams shows that many contain laterally persistent bounding surfaces that can be used to define multiple benches of coal within each seam. Inter-bench analyses from some of the most extensively mined seams in the central Appalachian Basin show that individual benches often have different spatial and quality trends. Hence, some component of whole-seam variability is a function of changes in the relative contribution of these different benches to the seam as a whole. Many coal benches also exhibit intra-bench variation in coal parameters. Intra-bench variation can be analyzed in terms of parameters such as sulfur content and ash yield in order to address changes in coal quality for regional resource evaluation. Intra-bench variation can also be analyzed in terms of a combination of palynologic, petrographic, and geochemical parameters, termed compositional groups, in order to better understand the development of the original mire systems. Compositional groups are defined by ranges of multiple criteria, which are inferred to owe their origin to the mire type in which they formed. Vertical changes in compositional groups within coal benches can be used to infer paleo-edaphic conditions during peat accumulation. If seam thickness is a product of bench configuration, and trends in compositional groups occur in benches, then trends in quality can be marginally predicted based upon seam thickness and inferred

  7. Coalbed methane exploration in the Lorraine Basin, France

    SciTech Connect

    Michaud, B.; Briens, F.; Girdler, D.

    1995-08-01

    DuPont Conoco Hydrocarbures has been involved in a Coalbed Methane (CBM) project in France since 1991. Coalbed methane exploration differs noticeably in several aspects from conventional oil and gas exploration. This paper is divided in three parts and discusses some geological, reservoir and drilling considerations relevant to the exploration and appraisal of a coalbed methane prospect. The first part presents geological issues such as data collection and evaluation of its associated value, building expertise to create a geological and geophysical model integrating the work of a multidisciplinary team, and assessing uncertainties of the data interpretation. A short review of the basin activity, geological and tectonic setting, and environment aspects is presented in order to illustrate some CBM exploration issues. The second part describes a comprehensive coalbed methane reservoir data acquisition program incorporating coal sample optical and chemical analyses, gas sample chromatography, canister desorption, fracture density of coal cores, and measurement of in-situ coal permeability and bounding-strata stress. Field practical concerns are then discussed such as on-site and off-site canister desorption, gas sample collection, rapid estimation of gas content, ash content, total bed moisture, and finally well testing alternatives for permeability and rock stress determination. The third part reviews drilling issues such as drilling and coring options for core hole size and casing size, rig site equipment requirements for continuous coring operations, including mud treatment equipment, core handling material and core work stations, alliance of national and foreign drilling contractors to optimize equipment and experience, and finally overview of coring procedures to identify best practices for pending operations. The paper is derived from Conoco`s experience in CBM exploration in the Lorraine Basin, North East of France.

  8. A search for stratiform massive-sulfide exploration targets in Appalachian Devonian rocks; a case study using computer-assisted attribute-coincidence mapping

    USGS Publications Warehouse

    Wedow, Helmuth

    1983-01-01

    The empirical model for sediment-associated, stratiform, exhalative, massive-sulfide deposits presented by D. Large in 1979 and 1980 has been redesigned to permit its use in a computer-assisted search for exploration-target areas in Devonian rocks of the Appalachian region using attribute-coincidence mapping (ACM). Some 36 gridded-data maps and selected maps derived therefrom were developed to show the orthogonal patterns, using the 7-1/2 minute quadrangle as an information cell, of geologic data patterns relevant to the empirical model. From these map and data files, six attribute-coincidence maps were prepared to illustrate both variation in the application of ACM techniques and the extent of possible significant exploration-target areas. As a result of this preliminary work in ACM, four major (and some lesser) exploration-target areas needing further study and analysis have been defined as follows: 1) in western and central New York in the outcrop area of lowermost Upper Devonian rocks straddling the Clarendon-Linden fault; 2) in western Virginia and eastern West Virginia in an area largely coincident with the well-known 'Oriskany' Mn-Fe ores; 3) an area in West Virginia, Maryland, and Virginia along and nearby the trend of the Alabama-New York lineament of King and Zietz approximately between 38- and 40-degrees N. latitude; and 4) an area in northeastern Ohio overlying an area coincident with a significant thickness of Silurian salt and high modern seismic activity. Some lesser, smaller areas suggested by relatively high coincidence may also be worthy of further study.

  9. Regional magnetotelluric surveys in hydrocarbon exploration, Parana' Basin, Brazil

    SciTech Connect

    Stanley, W.D.; Ohofugi, W.; Saad, A.R.

    1985-03-01

    The magnetotelluric geophysical method has been used effectively as a hydrocarbon exploration tool in the intracratonic Parana basin of South America. The 1-2 km thick surface basalts and buried diabase sills pose no problem for the magnetotelluric method because the natural electromagnetic fields used as the energy source pass easily through the basalt. Data for the regional study were taken on six profiles with soundings spaced 8 to 15 km apart. The magnetotelluric sounding data outline a linear uplift known as the Ponta Grossa arch. This major structural feature cuts across the northeast-trending intracratonic basin almost perpendicularly, and is injected with numerous diabase dikes. In the survey area, MT interpretations show that basalts have aggregate thicknesses of as much as 2 km (6,600 ft), and basement may be as much as 6 km (20,000 ft) below the surface. Over most of the basin, the basalts are covered by Upper Cretaceous to Holocene continental sediments of a few hundred meters thickness and are underlain by 2 to 4 km (6,600 to 13,100 ft) thick Paleozoic sediments with possible hydrocarbon potential. Significant electrical contrasts occur between the Permian sediments and older units, so that magnetotelluric measurements can give an indication of the regional thickness of the Permian and younger sediments to aid in interpreting hydrocarbon migration patterns and possible trap areas.

  10. Exploration targets in eastern half of Michigan basin

    SciTech Connect

    Catacosinos, P.A.

    1986-08-01

    Current economic conditions in the world's petroleum market mitigate against exploratory drilling. Yet, the geologic reality is that the US has an energy problem that worsens each year. Areas such as the Michigan basin must be thoroughly evaluated because untapped reserves may lie within the basin. Drilling continues for selected zones throughout much of the lower peninsula of Michigan, but the eastern part of the basin, from the Thumb area southward, remains relatively untested. Wells drilled there would encounter potential producing zones, including the Berea Sandstone, and the Dundee, Richfield, Trenton-Black River, and Bruggers formations. Niagaran reefs may be present, and Cambrian hydrocarbons, as yet undocumented in Michigan, may also exist. Drilling depths on the order of 10,000 ft or less will test the deepest zones. Anticlinal traps, which have been modified by faults and stratigraphic factors such as porosity trends and pinch-outs, are present in the area and are amenable to both geologic and seismic analysis. A sustained exploration effort and strategy using these techniques should produce a successful program.

  11. Exploration targets in the Great Basin of Utah

    SciTech Connect

    Allison, M.L.; Chidsey, T.C. Jr. )

    1993-08-01

    Three types of petroleum exploration targets are present in the Great Basin of Utah: structural traps in Tertiary sedimentary and volcanic rocks, unconformity traps of buried hills of Paleozoic rocks draped by Tertiary deposits, and structural traps related to thrusting where a wide variety of potential reservoir rocks are juxtaposed against Paleozoic source rocks. Tertiary targets are delineated by seismic surveys and consist of tilted fault blocks and faulted anticlines. The only success to date is Amoco's West Rozel field, in Great Salt Lake, which has in-place reserves estimated at 100 million to 1 billion bbl of oil, but is presently uneconomic. The oil is low gravity (4[degrees] API) with an extremely high sulfur content (12.5%). Little exploration has been done for these targets since the early 1980s when Amoco decided not to develop the field due to high water-cut and costs for offshore development.

  12. Acadian dextral transpression and synorogenic sedimentary successions in the Appalachians

    SciTech Connect

    Ferrill, B.A.; Thomas, W.A.

    1988-07-01

    The successive Seboomook-Littleton (northern Appalachians) and Catskill-Pocono (central Appalachians) clastic wedges suggest oblique convergence and southwestward migration of Acadian orogeny beginning in Early Devonian and continuing into Early Mississippian. Wrench-fault movement in Maritime Canada coincided with deposition of all but the earliest components of the Catskill-Pocono clastic wedge and continued into the Pennsylvanian. Contrasts between a thin, Lower to Middle Devonian shallow-shelf facies in the Alabama Appalachian fold-thrust belt and a time-equivalent, thick, shallowing-upward sedimentary to volcanic succession in the adjacent Talladega slate belt are interpreted to reflect a wrench-fault basin. A wrench-fault setting for Devonian rocks in Alabama integrated with manifestations of oblique convergence during the Acadian orogeny in the central and northern Appalachians can be accommodated in dextral transpression along the entire length of the Acadian Appalachian orogen.

  13. Remote sensing and image processing for exploration in frontier basins

    SciTech Connect

    Sabins, F.F. )

    1993-02-01

    A variety of remote sensing systems are available to explore the wide range of terrain in Central and South America and Mexico. The remote sensing data are recorded in digital form and must be computer-processed to produce images that are suitable for exploration. Landsat and SPOT images are available for most of the earth, but are restricted by cloud-cover. The broad terrain coverage recorded by Landsat thematic mapper (TM) is well suited for regional exploration. Color images are composited from various combinations of the 6 spectral bands to selectively enhance geologic features in different types of terrain. SPOT images may be acquired as stereo pairs which are valuable for structural interpretations. Radar is an active form of remote sensing that provides its own source of energy at wavelengths of centimeters which penetrate cloud-cover. Radar images are acquired at low depression angles to create shadows and highlights that enhance subtle geologic features. Satellite radar images of earth were recorded from two U.S. space shuttle missions in the 1980s and are currently recorded by the European Remote Sensing satellite and the Japanese Earth Resources Satellite. Mosaics of radar images acquired from aircraft are widely used in oil exploration, especially in cloud-covered regions. Typical images and computer processing method are illustrated with examples from various frontier basins.

  14. Assessment of Appalachian basin oil and gas resources: Devonian gas shales of the Devonian Shale-Middle and Upper Paleozoic Total Petroleum System: Chapter G.9 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Milici, Robert C.; Swezey, Christopher S.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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

  15. Operators renewing exploration in offshore basins of France

    SciTech Connect

    Lamiraux, C.; Mascle, A.

    1995-07-03

    Forty nine wells were drilled without success from the latter 1960s to the first half of the 1980s in French offshore areas. About 10 years of reduced activity followed this first phase of exploration. For a couple of years, these areas have been closely reassessed, taking into account the experience and data previously acquired. More particularly, a better understanding of tectonic processes at the origin of complex structural traps, a better taking into account of the distribution, quality, and maturation history of source rocks, together with significant improvements in seismic data acquisition-processing and basin modeling techniques, have led a few oil companies to apply for licenses in three offshore areas. The paper discusses prospects in the Bay of Biscay, the Iroise Sea and English Channel, and the Gulf of Lions.

  16. The evolution of Devonian hydrocarbon gases in shallow aquifers of the northern Appalachian Basin: Insights from integrating noble gas and hydrocarbon geochemistry

    NASA Astrophysics Data System (ADS)

    Darrah, Thomas H.; Jackson, Robert B.; Vengosh, Avner; Warner, Nathaniel R.; Whyte, Colin J.; Walsh, Talor B.; Kondash, Andrew J.; Poreda, Robert J.

    2015-12-01

    The last decade has seen a dramatic increase in domestic energy production from unconventional reservoirs. This energy boom has generated marked economic benefits, but simultaneously evoked significant concerns regarding the potential for drinking-water contamination in shallow aquifers. Presently, efforts to evaluate the environmental impacts of shale gas development in the northern Appalachian Basin (NAB), located in the northeastern US, are limited by: (1) a lack of comprehensive "pre-drill" data for groundwater composition (water and gas); (2) uncertainty in the hydrogeological factors that control the occurrence of naturally present CH4 and brines in shallow Upper Devonian (UD) aquifers; and (3) limited geochemical techniques to quantify the sources and migration of crustal fluids (specifically methane) at various time scales. To address these questions, we analyzed the noble gas, dissolved ion, and hydrocarbon gas geochemistry of 72 drinking-water wells and one natural methane seep all located ≫1 km from shale gas drill sites in the NAB. In the present study, we consciously avoided groundwater wells from areas near active or recent drilling to ensure shale gas development would not bias the results. We also intentionally targeted areas with naturally occurring CH4 to characterize the geochemical signature and geological context of gas-phase hydrocarbons in shallow aquifers of the NAB. Our data display a positive relationship between elevated [CH4], [C2H6], [Cl], and [Ba] that co-occur with high [4He]. Although four groundwater samples show mantle contributions ranging from 1.2% to 11.6%, the majority of samples have [He] ranging from solubility levels (∼45 × 10-6 cm3 STP/L) with below-detectable [CH4] and minor amounts of tritiogenic 3He in low [Cl] and [Ba] waters, up to high [4He] = 0.4 cm3 STP/L with a purely crustal helium isotopic end-member (3He/4He = ∼0.02 times the atmospheric ratio (R/Ra)) in samples with CH4 near saturation for shallow

  17. Exploration applications of geochemistry in the Midland Basin, Texas

    SciTech Connect

    Dow, W.G.; Talukdar, S.C. ); Harmon, L. )

    1990-05-01

    Reservoirs, source rocks, and crude oils were studied at Pegasas field on the eastern flank of the Central Basin platform. The field is a faulted anticlinal structure and produces oil and gas from seven geologically complex reservoirs ranging from the Ordovician Ellenburger to the Permian San Andres formations. A better understanding of the petroleum systems present should lead to improved exploration and development opportunities. Good to excellent-quality, mature oil-prone source rocks occur at numerous horizons between the Permian Spraberry and Ordovician Ellenburger formations. Oil-rock correlations indicate three major petroleum systems: Ordovician sources for oil in Ordovician, Silurian and Devonian reservoirs; Mississippian to Pennsylvanian sources for Pennsylvanian reservoired oils; and Permian sources for oils in Permian reservoirs. The Ordovician to Devonian system experienced peak oil generation, extensive vertical oil migration, and in-reservoir oil maturation in Triassic time; the Mississippian-Pennsylvanian system reached peak oil generation with limited vertical oil migration in Jurassic time; and the Permian system is just reaching peak oil generation and has had little or no vertical oil migration. The total amount of oil available to charge the field is several times the oil in place, and all available traps were filled to capacity. This implies substantial accumulations remain undiscovered in subtle stratigraphic and combination traps in the Pegasus field area. The same is probably true throughout the Midland basin. Integrated studies with geological, geophysical, engineering, and geochemical input can provide valuable exploration information on local as well as regional scales. Pegasus field examples include fault-block isolation reservoir segregation and waterflood or gas cycling efficiency. Such studies may also contribute information leading to lateral and vertical field extension wells.

  18. Devonian stratigraphy of the Appalachians

    SciTech Connect

    Ferrill, B.A.; Thomas, W.A.

    1985-01-01

    Lower and lower Middle Devonian (below the top of the Onondaga and equivalent) strata in the Appalachian unmetamorphosed fold-thrust belt are relatively thin and are laterally variable in lithology, thickness, and age. South of Virginia, thickness is less than 100 m; in Virginia and farther north, thickness ranges from 100 to 450 m. Locally, rocks of this age are unconformably absent in Pennsylvania and in Virginia and farther south. Clastic rocks dominate the interval in places along the southeastern margin of the fold-thrust belt and near pinch-outs at unconformities. Elsewhere, the interval is dominated by carbonate rocks. In contrast, thick sequences of lower Devonian rocks are preserved in Appalachian metamorphic belts in New England and in Alabama. The stratigraphic distribution of upper Middle (above the top of the Onondaga and equivalent) and Upper Devonian rocks is dominated by the widespread semicircular Catskill clastic wedge, centered on southeastern Pennsylvania. Near the depocenter, the succession grades upward from deep-water black shale, through shallow-marine sandstones and mudstones, to deltaic and fluvial red beds. These facies prograde both northwestward toward the craton and southwestward along structural strike. Pelitic rocks dominate the distal part of the wedge. Distribution of the Catskill clastic wedge reflects sediment transport onto the earlier Devonian shelf from an Acadian orogenic uplift. Local basins in Maine were probably not interconnected and reflect fault-block uplifts and pull-apart basins associated with wrench faults.

  19. Use of geophysical, geobotanical, and remotely sensed data in a low cost hydrocarbon exploration strategy for the Appalachians

    SciTech Connect

    Parrish, J.B.

    1985-01-01

    An integrated approach is developed at three scales: regional, subregional, and local. The principal problem addressed was that of how to make the transitional effectively from regional anomalies on the scale of tens of kilometers to a specific drilling site defined by an area on the order of tens of meters. The regional scale results, particularly the are magnetic anomalies, indicated several cross-structural lineaments which are indicative of basement discontinuities that were used to define an exploration area. For this subregional area two-dimensional data sets for Landsat MSS and digital terrain data were transformed and used to define the surficial location of the Wheeling-Needmore magnetic lineament within the subregional study area, indicating that a basement fault has influenced sedimentary structure. Two local-scale exploration areas were delineated. The southern area, which is in the vicinity of the NASA/Geosat Lost River, West Virginia test site was chosen for further study. An anomalous distribution of maples (Acer rubrum) was identified at Lost River in a region where chestnut oak (Quercus prinus) predominates. Soil gas measurements in the field and an in vitro study of seedling response to methane gas supported the hypothesis that high soil gas methane content at the surface is responsible for the geobotanical anomaly. Based on the findings of this study, the proposed minimal-cost exploration strategy should be useful in vegetated terrains in which there are surface hydrocarbon seeps.

  20. Exploration in the Savannakhet Basin, Peoples Democratic Republic of Laos

    SciTech Connect

    Cullen, P.J.; Wright, S.C. ); Kearney, C.J.; Pink, A.T. )

    1994-07-01

    The collision and suturing of four continental fragments during the Early Permian to the Middle Triassic formed present-day southeast Asia. Collapse of the overthickened crust in the Late Triassic (Indosinian) produced crustal extension and led to the development of an en echelon system of half grabens, which stretched across northeast Thailand and south-central Laos. Deposition of alluvial and fluvial sandstones and lacustrine mudstones rapidly infilled these depocenters and was succeeded by widespread continental mudstone deposition with occasional marine incursions through Jurassic and Cretaceous. The Late Cretaceous collision of the Kohistan arc and subsequent collision of India with Eurasia (Himalayan orogeny) inverted these half grabens along the preexisting extensional faults, producing large-scale anticlines. Continued regional uplift of the Khorat plateau area and denudation of the land surface has removed up to 3 km of sediments from the crests of the inversion anticlines. The Savannakhet basin lies in the south-central part of the Peoples Democratic Republic of Laos, between the Mekong River and the eastern border with Vietnam. A group led by Enterprise Oil Exploration Ltd. licensed this area for hydrocarbon exploration in 1989. Gravity, aeromagnetic, seismic, geological, and geochemical data have all been acquired and used in an integrated interpretation of the geology and hydrocarbon prospectivity of the license area.

  1. Stratigraphic framework of Cambrian and Ordovician rocks in the central Appalachian Basin from Medina County, Ohio, through southwestern and south-central Pennsylvania to Hampshire County, West Virginia

    USGS Publications Warehouse

    Ryder, Robert T.; Harris, Anita G.; Repetski, John E.; revised and digitized by Crangle, Robert D.

    2003-01-01

    A 275-mi-long restored stratigraphic cross section from Medina County, Ohio, through southwestern and south-central Pennsylvania to Hampshire County, W. Va., provides new details on Cambrian and Ordovician stratigraphy in the central Appalachian basin and the structure of underlying Precambrian basement rocks. From west to east, the major structural elements of the block-faulted basement in this section are (1) the relatively stable, slightly extended craton, which includes the Wooster arch, (2) the fault-controlled Ohio-West Virginia hinge zone, which separates the craton from the adjoining Rome trough, (3) the Rome trough, which consists of an east-facing asymmetric graben and an overlying sag basin, and (4) a positive fault block, named here the South-central Pennsylvania arch, which borders the eastern margin of the graben part of the Rome trough. Pre-Middle Ordovician structural relief on Precambrian basement rocks across the down-to-the-west normal fault that separates the Rome trough and the adjoining South-central Pennsylvania arch amounted to between 6,000 and 7,000 ft. The restored cross section shows eastward thickening of the Cambrian and Ordovician sequence from about 3,000 ft near the crest of the Wooster arch at the western end of the section to about 5,150 ft at the Ohio-West Virginia hinge zone adjoining the western margin of the Rome trough to about 19,800 ft near the depositional axis of the Rome trough. East of the Rome trough, at the adjoining western edge of the South-central Pennsylvania arch, the Cambrian and Ordovician sequence thins abruptly to about 13,500 ft and then thins gradually eastward across the arch to about 12,700 ft near the Allegheny structural front and to about 10,150 ft at the eastern end of the restored section. In general, the Cambrian and Ordovician sequence along this section consists of four major lithofacies that are predominantly shallow marine to peritidal in origin. In ascending stratigraphic order, the lithofacies

  2. Hybridizing rapidly exploring random trees and basin hopping yields an improved exploration of energy landscapes.

    PubMed

    Roth, Christine-Andrea; Dreyfus, Tom; Robert, Charles H; Cazals, Frédéric

    2016-03-30

    The number of local minima of the potential energy landscape (PEL) of molecular systems generally grows exponentially with the number of degrees of freedom, so that a crucial property of PEL exploration algorithms is their ability to identify local minima, which are low lying and diverse. In this work, we present a new exploration algorithm, retaining the ability of basin hopping (BH) to identify local minima, and that of transition based rapidly exploring random trees (T-RRT) to foster the exploration of yet unexplored regions. This ability is obtained by interleaving calls to the extension procedures of BH and T-RRT, and we show tuning the balance between these two types of calls allows the algorithm to focus on low lying regions. Computational efficiency is obtained using state-of-the art data structures, in particular for searching approximate nearest neighbors in metric spaces. We present results for the BLN69, a protein model whose conformational space has dimension 207 and whose PEL has been studied exhaustively. On this system, we show that the propensity of our algorithm to explore low lying regions of the landscape significantly outperforms those of BH and T-RRT. PMID:26714673

  3. Hybridizing rapidly exploring random trees and basin hopping yields an improved exploration of energy landscapes.

    PubMed

    Roth, Christine-Andrea; Dreyfus, Tom; Robert, Charles H; Cazals, Frédéric

    2016-03-30

    The number of local minima of the potential energy landscape (PEL) of molecular systems generally grows exponentially with the number of degrees of freedom, so that a crucial property of PEL exploration algorithms is their ability to identify local minima, which are low lying and diverse. In this work, we present a new exploration algorithm, retaining the ability of basin hopping (BH) to identify local minima, and that of transition based rapidly exploring random trees (T-RRT) to foster the exploration of yet unexplored regions. This ability is obtained by interleaving calls to the extension procedures of BH and T-RRT, and we show tuning the balance between these two types of calls allows the algorithm to focus on low lying regions. Computational efficiency is obtained using state-of-the art data structures, in particular for searching approximate nearest neighbors in metric spaces. We present results for the BLN69, a protein model whose conformational space has dimension 207 and whose PEL has been studied exhaustively. On this system, we show that the propensity of our algorithm to explore low lying regions of the landscape significantly outperforms those of BH and T-RRT.

  4. Revisiting the Hubbert-Rubey pore pressure model for overthrust faulting: Inferences from bedding-parallel detachment surfaces within Middle Devonian gas shale, the Appalachian Basin, USA

    NASA Astrophysics Data System (ADS)

    Aydin, Murat G.; Engelder, Terry

    2014-12-01

    Both bedding-parallel slickensides and cleavage duplexes are forms of mesoscopic-scale detachment faulting populating black (Marcellus and Geneseo/Burket) and intervening gray (Mahantango) shales of the Middle Devonian, a section known for abnormal pore pressure below the Appalachian Plateau. The abundance and the orientation of slickensides and cleavage duplexes in the more organic-rich black shale relative to gray shale suggests that maturation-related abnormal pore pressure facilitates detachment, a mesoscopic manifestation of the Hubbert-Rubey pore pressure model for overthrust faulting. The former are discrete slip surfaces whereas the latter consists of nested, anastomosing slip surfaces, either cutting through bedding or on disrupted bedding surfaces stacked as mesoscopic versions of thrust duplexes. Cleavage duplexes are between a few cm and over 1 m thick with their hanging walls commonly transported toward the Appalachian foreland, regardless of local limb dip. Cleavage duplexes are most common near the stratigraphic maximum flooding surface, the organic-rich section most prone to develop maturation-related pore pressure in the Middle Devonian gas shales. Bedding-parallel slickensides are somewhat more evenly distributed in the black shale but also found in overlying gray shale. In both black and gray shales, slickensides are more abundant on the limbs of folds, an indication of pore-pressure-related flexural-slip folding. On the macroscopic scale, the Pine Mountain Block of the Southern Appalachian Mountains was enabled by a basal detachment cutting along the Upper Devonian Chattanooga black shale which has a thermal maturity sufficient for the generation of abnormal pore pressure. The Pine Mountain block is a large-scale overthrust showing little evidence of collapse of the hinterland side, a credible example of a pore-pressure-aided overthrust fault block of the type envisioned by the Hubbert-Rubey model.

  5. Geologic Analysis of Priority Basins for Exploration and Drilling

    SciTech Connect

    Carroll, H.B.; Reeves, T.K.

    1999-04-27

    There has been a substantial decline in both exploratory drilling and seismic field crew activity in the United States over the last 10 years, due primarily to the declining price of oil. To reverse this trend and to preserve the entrepreneurial independent operator, the U.S. DOE is attempting to encourage hydrocarbon exploration activities in some of the under exploited regions of the United States. This goal is being accomplished by conducting broad regional reviews of potentially prospective areas within the lower 48 states. Data are being collected on selected areas, and studies are being done on a regional scale generally unavailable to the smaller independent. The results of this work will be made available to the public to encourage the undertaking of operations in areas which have been overlooked until this project. Fifteen criteria have been developed for the selection of study areas. Eight regions have been identified where regional geologic analysis will be performed. This report discusses preliminary findings concerning the geology, early tectonic history, structure and potential unconventional source rocks for the Black Mesa basin and South Central states region, the two highest priority study areas.

  6. Possible continuous-type (unconventional) gas accumulation in the Lower Silurian "Clinton" sands, Medina Group and Tuscarora Sandstone in the Appalachian Basin; a progress report of the 1995 project activities

    USGS Publications Warehouse

    Ryder, Robert T.; Aggen, Kerry L.; Hettinger, Robert D.; Law, Ben E.; Miller, John J.; Nuccio, Vito F.; Perry, William J.; Prensky, Stephen E.; Filipo, John J.; Wandrey, Craig J.

    1996-01-01

    INTRODUCTION: In the U.S. Geological Survey's (USGS) 1995 National Assessment of United States oil and gas resources (Gautier and others, 1995), the Appalachian basin was estimated to have, at a mean value, about 61 trillion cubic feet (TCF) of recoverable gas in sandstone and shale reservoirs of Paleozoic age. Approximately one-half of this gas resource is estimated to reside in a regionally extensive, continuous-type gas accumulation whose reservoirs consist of low-permeability sandstone of the Lower Silurian 'Clinton' sands and Medina Group (Gautier and others, 1995; Ryder, 1995). Recognizing the importance of this large regional gas accumulation for future energy considerations, the USGS initiated in January 1995 a multi-year study to evaluate the nature, distribution, and origin of natural gas in the 'Clinton' sands, Medina Group sandstones, and equivalent Tuscarora Sandstone. The project is part of a larger natural gas project, Continuous Gas Accumulations in Sandstones and Carbonates, coordinated in FY1995 by Ben E. Law and Jennie L. Ridgley, USGS, Denver. Approximately 2.6 man years were devoted to the Clinton/Medina project in FY1995. A continuous-type gas accumulation, referred to in the project, is a new term introduced by Schmoker (1995a) to identify those natural gas accumulations whose reservoirs are charged throughout with gas over a large area and whose entrapment does not involve a downdip gas-water contact. Gas in these accumulations is located downdip of the water column and, thus, is the reverse of conventional-type hydrocarbon accumulations. Commonly used industry terms that are more or less synonymous with continuous-type gas accumulations include basin- centered gas accumulation (Rose and others, 1984; Law and Spencer, 1993), tight (low-permeability) gas reservoir (Spencer, 1989; Law and others, 1989; Perry, 1994), and deep basin gas (Masters, 1979, 1984). The realization that undiscovered gas in Lower Silurian sandstone reservoirs of the

  7. Carboniferous stratigraphy of the Appalachians

    SciTech Connect

    Hines, R.A.; Thomas, W.A.

    1985-01-01

    Carboniferous rocks in the Appalachian fold-thrust belt and foreland basins include parts of four clastic wedges. Distribution, composition, and ages of the clastic wedges record diachronous orogenic uplifts along the Appalachian margin. Lower Mississippian Pocono sandstones form the upper part of the Catskill-Pocono clastic wedge, which includes the Devonian Catskill deltaic facies. Pocono rocks reflect clastic sediments transport toward the northwest and west from an orogenic source east of the Pennsylvania salient. The upper Mississippian-Pennsylvanian Mauch Chunk-Pottsville clastic wedge prograded westward and southwestward from the Pennsylvania salient over Mississippian limestone. The southwestern limit of the Mauch Chunk-Pottsville clastic wedge is overlapped in the Virginia recess by the oppositely directed Pennington-Lee clastic wedge. The Upper Mississippian-Pennsylvanian Pennington-Lee clastic wedge prograded northeastward and northwestward from the Tennessee salient. Southwestward in the Alabama recess, the Pennington clastic facies grades into Mississippian limestone, and Lee-equivalent sandstones extend over the limestone. In the western part of the Alabama recess, Upper Mississippian-Lower Pennsylvanian delta systems prograded northeastward over the Mississippian carbonate facies. These clastic sediments are an eastern shelf-delta part of a thick clastic wedge that consists of turbidites in the Ouachita salient. The eastern fringe of the Ouachita clastic wedge merges with the southwestward-prograding Pennington-Lee clastic wedge above Mississippian carbonate rocks in the Alabama recess.

  8. Composition of natural gas and crude oil produced from 10 wells in the Lower Silurian "Clinton" Sandstone, Trumbull County, Ohio: Chapter G.7 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Burruss, Robert A.; Ryder, Robert T.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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.

  9. Petroleum geology of Cook Inlet basin - an exploration model

    USGS Publications Warehouse

    Magoon, L.B.; Claypool, G.E.

    1981-01-01

    Oil exploration commenced onshore adjacent to lower Cook Inlet on the Iniskin Peninsula in 1900, shifted with considerable success to upper Cook Inlet from 1957 through 1965, then returned to lower Cook Inlet in 1977 with the COST well and Federal OCS sale. Lower Cook Inlet COST No. 1 well, drilled to a total depth of 3,775.6 m, penetrated basinwide unconformities at the tops of Upper Cretaceous, Lower Cretaceous, and Upper Jurassic strata at 797.1, 1,540.8, and 2,112.3 m, respectively. Sandstone of potential reservoir quality is present in the Cretaceous and lower Tertiary rocks. All siltstones and shales analyzed are low (0 to 0.5 wt. %) in oil-prone organic matter, and only coals are high in humic organic matter. At total depth, vitrinite readings reached a maximum ave age reflectance of 0.65. Several indications of hydrocarbons were present. Oil analyses suggest that oils from the major fields of the Cook Inlet region, most of which produce from the Tertiary Hemlock Conglomerate, have a common source. More detailed work on stable carbon isotope ratios and the distribution of gasoline-range and heavy (C12+) hydrocarbons confirms this genetic relation among the major fields. In addition, oils from Jurassic rocks under the Iniskin Peninsula and from the Hemlock Conglomerate at the southwestern tip of the Kenai lowland are members of the same or a very similar oil family. The Middle Jurassic strata of the Iniskin Peninsula are moderately rich in organic carbon (0.5 to 1.5 wt. %) and yield shows of oil and of gas in wells and in surface seeps. Extractable hydrocarbons from this strata are similar in chemi al and isotopic composition to the Cook Inlet oils. Organic matter in Cretaceous and Tertiary rocks is thermally immature in all wells analyzed. Oil reservoirs in the major producing fields are of Tertiary age and unconformably overlie Jurassic rocks; the pre-Tertiary unconformity may be significant in exploration for new oil reserves. The unconformable relation

  10. "We're All Appalachian."

    ERIC Educational Resources Information Center

    Banker, Mark

    2002-01-01

    A teacher at a Knoxville college preparatory school challenges his students to analyze stereotypes about Appalachia and recognize that acceptance of their own Appalachian-ness is vital to their personal well-being and that of the region. Comparisons of Appalachians with Hispanics in northern New Mexico reveal common issues of land use, cultural…

  11. Mesozoic rift basins in western desert of Egypt, their southern extension and impact on future exploration

    SciTech Connect

    Taha, M.A. )

    1988-08-01

    Rift basins are a primary target of exploration in east, central, and west Africa. These intracratonic rift basins range in age from the Triassic to the Neogene and are filled with lagoonal-lacustrine sand-shale sequences. Several rift basins may be present in the Western Desert of Egypt. In the northeastern African platform, the Mesozoic Tethyan strand lines were previously interpreted to have limited southern extension onto the continent. This concept, based upon a relatively limited amount of subsurface data, has directed and focused the exploration for oil and gas to the northernmost 120 km of the Western Desert of Egypt. Recent well and geophysical data indicate a southerly extension of mesozoic rift basins several hundred kilometers inland from the Mediterranean Sea. Shushan/Faghur and Abu Gharadig/Bahrein basins may represent subparallel Mesozoic basins, trending northeast-southwest. Marine Oxfordian-Kimmeridgian sediments were recently reported from wells drilled approximately 500 km south of the present-day Mediterranean shoreline. The link of these basins with the Sirte basin to the southwest in Libya is not well understood. Exploration is needed to evaluate the hydrocarbon potential of such basins.

  12. U-Pb age of zircon crystals from the upper banner tonstein (Middle Pennsylvanian), Virginia: Absolute age of the Lower Pennsylvanian-Middle Pennsylvanian boundary and depositional rates for the Middle Pennsylvanian, central appalachian basin

    USGS Publications Warehouse

    Lyons, P.C.; Krogh, T.E.; Kwok, Y.Y.; Zodrow, E.L.

    1997-01-01

    The Upper Banner tonstein, a kaolinized volcanic ash bed that occurs about 90 m above the base of the Middle Pennsylvanian Series in Virginia, is the oldest known Middle Pennsylvanian tonstein in the Appalachian basin. On the basis of palynostratigraphy, the Upper Banner coal bed correlates approximately with the Langsettian-Duckmantian (ex Westphalian A-B) boundary in Europe. Stratigraphically, the Upper Banner tonstein occurs 440-480 m below the Fire Clay tonstein, which in turn is 25-50 m below the marine Magoffin Member of the Breathitt Formation, the approximate correlative of the Agir Marine Band that marks the Dunckmantian-Bolsovian (ex Westphalian C) boundary in Europe. Six single-crystal U-Pb zircon ages were determined for the Upper Banner tonstein. Of these, four overlap concordia within uncertainties and have 206Pb/238U ages that range from 306 to 310??1 Ma. Another analysis falls in the same group but plots slightly to the right of the curve, whereas a single analysis of a low uranium zircon grain gives an age of 316??1 Ma. Variation in ages is outside of analytical uncertainty; hence, variable amounts of recent Pb loss is implied, and the most probable (minimum) depositional age is given by the oldest value at 316??1 Ma - an age consistent with a mean sanidine 40Ar/39Ar plateau age of 311.2??0.7 Ma for the stratigraphically younger Fire Clay tonstein. Thus, the Upper Banner tonstein-Fire Clay tonstein interval is about 5 ?? 1 m.y. This period of time for the Dunckmantian Stage is in good agreement with the Hess and Lippolt (1986) and Hess et al. (1988) chronology for the Duckmantian based on 40Ar/39Ar plateau methods for Westphalian tonsteins. Also, on the basis of this period of time, calculated sedimentation rates (decompacted) od 66-165 m/m.y. were determined for the lower part of the Middle Pennsylvanian Series in the central Appalachian basin. These rates are consistent with the sedimentation rates for shallow-water marine siliciclastic sediments

  13. Basin center - fractured source rock plays within tectonically segmented foreland (back-arc) basins: Targets for future exploration

    SciTech Connect

    Weimer, R.J.

    1994-09-01

    Production from fractured reservoirs has long been an industry target, but interest in this type play has increased recently because of new concepts and technology, especially horizontal drilling. Early petroleum exploration programs searched for fractured reservoirs from shale, tight sandstones, carbonates, or basement in anticlinal or fault traps, without particular attention to source rocks. Foreland basins are some of the best oil-generating basins in the world because of their rich source rocks. Examples are the Persian Gulf basin, the Alberta basin and Athabasca tar sands, and the eastern Venezuela basin and Orinoco tar sands. Examples of Cretaceous producers are the wrench-faulted La Paz-Mara anticlinal fields, Maracaibo basin, Venezuela; the active Austin Chalk play in an extensional area on the north flank of the Gulf of Mexico continental margin basin; and the Niobrara Chalk and Pierre Shale plays of the central Rocky Mountains, United States. These latter plays are characteristic of a foreland basin fragmented into intermontane basins by the Laramide orogeny. The Florence field, Colorado, discovered in 1862, and the Silo field, Wyoming, discovered in 1980, are used as models for current prospecting and will be described in detail. The technologies applied to fracture-source rock plays are refined surface and subsurface mapping from new log suites, including resistivity mapping; 3D-3C seismic, gravity, and aeromagnetic mapping; borehole path seismic mapping associated with horizontal drilling; fracture mapping with the Formation MicroScanner and other logging tools; measurements while drilling and other drilling and completion techniques; surface geochemistry to locate microseeps; and local and regional lineament discrimination.

  14. Aeromagnetic exploration over the East Antarctic Ice Sheet: A new view of the Wilkes Subglacial Basin

    NASA Astrophysics Data System (ADS)

    Ferraccioli, Fausto; Armadillo, Egidio; Jordan, Tom; Bozzo, Emanuele; Corr, Hugh

    2009-12-01

    The Wilkes Subglacial Basin represents an approximately 1400 km-long and up to 600 km wide subglacial depression, buried beneath the over 3 km-thick East Antarctic Ice Sheet. Contrasting models, including rift models and flexural models, have been previously put forward to explain the tectonic origin of this enigmatic basin, which is located in the largely unexplored hinterland of the Transantarctic Mountains. A major aerogeophysical survey was flown during the 2005-06 austral summer to explore the Wilkes Subglacial Basin. Our new airborne radar dataset reveals that the Wilkes Subglacial Basin contains several subglacial basins, which are considerably deeper than previously mapped. Major aeromagnetic lineaments are detected from total field, pseudo-gravity, tilt derivative and Euler Deconvolution maps. These aeromagnetic lineaments reveal that the Wilkes Subglacial Basin and its sub-basins are structurally controlled. Comparison between aeromagnetic signatures over the Wilkes Subglacial Basin region and the Cordillera in North America, suggests that the basin contains a former broad backarc basin and fold-and-thrust belts, forming the transition between a Precambrian craton and the Ross Orogen. The eastern margin of the Wilkes Subglacial Basin is imposed upon the Prince Albert Fault System and the Priestley Fault. These faults may have been reactivated in the Cenozoic, as major strike-slip faults. The western margin of the Wilkes Subglacial Basin is located along the southern extension of the Precambrian-age Mertz Shear Zone and marks the edge of the Terre Adélie Craton. High-frequency aeromagnetic anomalies in the Wilkes Subglacial Basin image large volumes of Jurassic tholeiites, which were intruded into and extruded over Beacon sediments in a possible rift setting. Depth-estimates of magnetic anomaly sources and forward modelling indicate that major Cretaceous and Cenozoic rift basins with thick sedimentary infill, comparable to the deep Ross Sea Rift basins

  15. Appalachian Play Fairway Analysis Seismic Hazards Supporting Data

    DOE Data Explorer

    Frank Horowitz

    2016-07-20

    These are the data used in estimating the seismic hazards (both natural and induced) for candidate direct use geothermal locations in the Appalachian Basin Play Fairway Analysis by Jordan et al. (2015). xMin,yMin -83.1407,36.7461 : xMax,yMax -71.5175,45.1729

  16. A Selected Appalachian Bibliography.

    ERIC Educational Resources Information Center

    Taylor, Mary K., Comp.

    This bibliography was compiled to assist high school and junior college teachers in planning a classroom unit on Appalachian literature. It contains suggested fiction and poetry, as well as general background reading. Topic entries are: Bibliographies; Chicago; Fiction; Folklore; General Background Reading (includes psychological, sociological and…

  17. The 1911 Quadrant offshore Namibia; Exploration in a virgin basin

    SciTech Connect

    Holtar, E.; Forsberg, A.

    1995-08-01

    As a result of the first licensing round in independent Namibia, the Namibian authorities in 1992 awarded five offshore licenses to five different companies or groups of companies. License no. 001 was awarded in 1992 to a group consisting of three Norwegian oil companies, Norsk Hydro, Saga Petroleum and Statoil, with Hydro as the operator. Somewhat later Bow Valley Energy (now Talisman Energy) farmed in. Since 1992 a seismic survey of 7200 km has been acquired over the license area that covers 11.619 sq. Km of the Walvis Basin. This basin was undrilled until the 1911/15-1 well was finished at a depth of 4586mRKB in early 1994. The sedimentary succession of the 1911/15-1 well reflects a depositional history that postdates the Neocorman Etendeka plateau basalts found onshore Namibia. After the onset of the drift phase in late Hauterivian times, the Walvis Basin subsided and eventually a marine transgression took place. Shallow marine platform sedimentation then prevailed until an Albian tectonic event resulted in complex block faulting and the formation of several sub basins. Subsequent volcanic activity created a series of volcanic centres localized on the Walvis Ridge bathymetric feature. In early Late Cretaceous the Southern African craton was uplifted relative to the shelf, leading to the formation of large scale westward prograding wedges. Later sedimentation largely followed the evolution of a passive continental margin, responding to relative sealevel changes and paleoclimate. A stratigraphic breakdown of the Northern Namibian offshore is proposed, and compared to South African and Angolan nomenclature.

  18. Regional frontier exploration in Sinu basin, northwestern Colombia

    SciTech Connect

    Lindberg, F.A.; Ellis, J.M.; Dekker, L.L.

    1989-03-01

    In 1983, Gulf and Ecopetrol undertook a regional hydrocarbon evaluation of northwestern Colombia, during the course of which much of the Sinu basin was mapped by field geologists aided by low-altitude aerial photographs. Additional seismic and airborne radar data were acquired to assist in developing a regional structural model. The dominant structures of the Sinu basin were produced by westward-vergent thrust faults, which are offset on the order of 10 to 20 km by northwest-southeast-trending compartmental faults. Numerous mud volcanos are surface expressions of overpressured shales, which migrate upward along both thrust and strike-slip faults. Thrust faults are expressed, on the surface, by steep-sided, asymmetrical anticlines, which are separated by broad synclines filled with clastics shed during Tertiary thrusting. The extremely thick section of Tertiary sediments is dominated by shale but contains some potential reservoir sandstones. These resistive sandstones could be accurately mapped on the radar imagery and projected into the subsurface allowing traps to be better defined. Combining field geology with geologic interpretation of aerial photographs and radar images was very effective in developing a regional structural framework of the Sinu basin.

  19. Polish permian basin: Lithofacies traps for gas within the Rotliegende deposits as a new exploration potential

    SciTech Connect

    Karnkowski, P.H. )

    1993-09-01

    Rotliegende deposits are the most prospective reservoir gas rocks in the Polish Permian basin. Thirty years of their exploration have led to location of numerous gas fields in the upper-most part of these series, particularly in the area of the Fore-Sudetic monocline. Up to this time, exploration studies concentrated mainly on structural objects, and most of the structures were positive gas traps. Well and seismic data also indicate an occurrence of lithofacies gas traps; they occur mainly in the sandstone zones within the fanglomerates surrounding the Wolsztyn Ridge. When comparing the facies regularities in the known gas fields in the German Permian basin (interfingering sandstones and claystones) to the facies patterns of the Polish Permian basin, one may suspect similar exploration possibilities. These are the first promising results. Advances in analysis of the Rotliegende depositional systems will enable us to create a new exploration potential.

  20. Exploration for geothermal energy in Arizona basin and range

    SciTech Connect

    Witcher, J.C.; Ruscetta, C.A.

    1982-07-01

    A summary of the results and interpretations of heat flow and geochemistry studies in the Safford Basin, Arizona, is presented. Numerous artesian wells discharge thermal water at 30 to 50/sup 0/C. The Artesia anomaly is characterized by high soil mercury, ranging from 225 ppb to 380 ppb, and high apparent heat flow, ranging from 1.35 ..mu..cal/cm/sup 2/sec at a depth of 65 to 95 ft to 5.25 ..mu..cal/cm/sup 2/sec at a depth of 70 to 130 ft. It is concluded that the factors point toward a hydrothermal convention system possibly controlled by basement structure. (MJF)

  1. Syn- to post-Taconian basin formation in the Southern Québec Appalachians, Canada: constraints from detrital zircon U-Pb geochronology

    NASA Astrophysics Data System (ADS)

    Perrot, Morgann; Tremblay, Alain; David, Jean

    2015-04-01

    In Southern Québec, In the Southern Quebec Appalachians, the Laurentian continental margin (Humber zone) and adjacent oceanic domain of the Dunnage zone were amalgamated during the Ordovician Taconian orogeny. The Dunnage zone includes ophiolites, overlying synorogenic Ordovician deposits of both the Saint-Daniel Mélange and Magog Group and the remnants of a peri-Laurentian volcanic arc, the Ascot complex. However, recently-acquired detrital zircons geochronological data challenge some aspects of the formation and evolution the Magog Group as documented so far. The Magog Group consists of ~3 km pile of sandstone, felsic volcaniclastic rocks, graphitic slate and sandstone at the base (Frontière, Etchemin and Beauceville formations) overlain by a ~7 km-thick of a turbidites flysch sequence, constituting the St-Victor Formation at the top. The maximum age limit for the Magog Group is currently considered to be Caradocian based on graptolite fauna. This has been proven consistent with a 462 +5/-4 Ma (U-Pb ID-TIMS) from a felsic tuff of the Beauceville Formation, but in obvious contradiction with a detrital zircon U-Pb age of 424  6 Ma recently measured in the St-Victor Formation. A detrital zircon U-Pbgeochronology study (LA-HR-ICPMS), focused on the St-Victor Formation, has been therefore initiated in order to better constrain the age and tectonic evolution of the Magog Group. Results were treated according to a Bayesian mixture modeling to highlight different age populations. A feldspar-rich sandstone, directly overlying the Ascot Complex (ca. 460 Ma) and belonging to the base of the St-Victor Formation, yielded ages as young as 431 ± 3 Ma (Wenlockian). Higher in the stratigraphy, a quartz-feldspars sandstone sample contains zircons as young as 419 ±2 Ma (Pridolian). Finally, another sandstone sample from the stratigraphic top of the analyzed sequence yielded a bimodal age distribution, showing prominent populations clustering around ca. 950 Ma and ca. 435 Ma

  2. Analysis of characteristics of simulated flows from small surface-mined and undisturbed Appalachian watersheds in the Tug Fork basin of Kentucky, Virginia, and West Virginia

    USGS Publications Warehouse

    Scott, A.G.

    1984-01-01

    Hydrologic and climatologic data were collected at 10 small, mined and unmined watersheds in the Tug Fork basin of Kentucky, Virginia, and West Virginia. These data included continuous records of discharge, precipitation, and air temperature. Daily records of sediment concentrations and sediment discharges were also obtained and periodic observations of water-quality data taken. A compilation of all these data is presented. The observed climatic and hydrologic data from these basins were used to calibrate the U.S. Geological Survey Precipitation-Runoff Modeling System for each watershed. The calibrated models of each basin were then used with a set of nearby, long-term climatic data to simulate a long record of stream-flow. A 68-year record of daily streamflow and 57 years of annual peaks were simulated for each site. These simulated records were analyzed to obtain flood-frequency curves, flow-duration curves, mean-annual discharges, and the 7-day, 10-year low flow for each site. The flow characteristics computed from the simulated records of discharge were analyzed graphically and statistically by regression analysis to investigate the degree of relationship and to define the relationship between mining and runoff. For this sample of small basins, peak flows, discharges for 10- and 50-percent flow durations, and mean-annual flows are directly related to percent of drainage area disturbed (measured from aerial photos) and drainage area. Percent of drainage area disturbed is generally a more statistically significant estimator of discharge than drainage area, particularly for peak flows of higher recurrence intervals. (USGS)

  3. The Role of Language in Interactions with Others on Campus for Rural Appalachian College Students

    ERIC Educational Resources Information Center

    Dunstan, Stephany Brett; Jaeger, Audrey J.

    2016-01-01

    Dialects of English spoken in rural, Southern Appalachia are heavily stigmatized in mainstream American culture, and speakers of Appalachian dialects are often subject to prejudice and stereotypes which can be detrimental in educational settings. We explored the experiences of rural, Southern Appalachian college students and the role speaking a…

  4. Depositional setting of Ordovician and Cambrian rocks in central Appalachian basin along a section from Morrow County, Ohio, to Calhoun County, West Virginia

    SciTech Connect

    Ryder, R.T.

    1988-08-01

    A 200-mi (320 km) long restored stratigraphic section from Morrow County, Ohio, to Calhoun County, West Virginia, contrasts Ordovician and Cambrian rocks deposited on a relatively stable shelf with those deposited in rift and postrift basins. Lithologic data are from commercial logs and from detailed descriptions of cores in five of the nine drill holes used to construct the section. Particularly instructive was the 2,352 ft (717 m) of core from the Hope Natural Gas 9634 Power Oil basement test in Wood County, West Virginia. Rift basin deposits are dominated by medium to dark-gray argillaceous limestone, argillaceous siltstone, and by green-gray to black shale of probable subtidal origin. Dolomite is the dominant rock type in the postrift basin and adjacent stable shelf deposits. The upper part of the postrift sequence, composed of the Middle Ordovician Black River Limestone, the Middle Ordovician Trenton Limestone, and Middle and Upper Ordovician Antes (Utica) Shale with a high organic content, represents deposition in gradually deepening water on an open shelf.

  5. Environmental Compliance for Oil and Gas Exploration and Production

    SciTech Connect

    Hansen, Christine

    1999-10-26

    The Appalachian/Illinois Basin Directors is a group devoted to increasing communication among the state oil and gas regulatory agencies within the Appalachian and Illinois Basin producing region. The group is comprised of representatives from the oil and gas regulatory agencies from states in the basin (Attachment A). The directors met to discuss regulatory issues common to the area, organize workshops and seminars to meet the training needs of agencies dealing with the uniqueness of their producing region and perform other business pertinent to this area of oil and gas producing states. The emphasis of the coordinated work was a wide range of topics related to environmental compliance for natural gas and oil exploration and production.

  6. Using potential field data for petroleum exploration targeting, Amadeus Basin, Australia

    NASA Astrophysics Data System (ADS)

    Dentith, Mike; Cowan, Duncan

    2011-09-01

    The Amadeus Basin, a large Proterozoic basin located in central Australia, is one of the least explored onshore petroleum-bearing basins with proven reserves in Australia. The size and remoteness of the Amadeus Basin makes ground exploration expensive so this study uses aerogravity and aeromagnetic data to assess petroleum prospectivity. In the western part of the Amadeus Basin the Gillen Petroleum System is considered most significant; this system has the important characteristic that the source in the Bitter Springs Formation is stratigraphically higher than the potential reservoirs within the Dean/Heavitree Quartzite. Thin skinned deformation is expected at the source level and above, with detachments at evaporitic horizons, but deformation of the reservoir is expected to be thick-skinned. This model can form the basis for predicting potential field responses. The most prospective areas are where: (i) gravity suggests basement (and reservoir) is shallow; (ii) magnetics maps fold-thrust complexes (structural trap); and (iii) these features occur adjacent to gravity lows, indicative of significant thicknesses of basin fill (source at depth and below reservoir). Faults at the margins of the depocentre (mapped using magnetic data) provide a possible migration path for the hydrocarbons. Favourable scenarios for younger petroleum systems are antiforms in fold-thrust complexes in units assigned to the Boord Formation and younger units. The juxtaposition of these structures with depocentres suggested by negative gravity anomalies constitutes a favourable exploration scenario. Regardless of specific exploration targets, this study demonstrates that airborne gravity and magnetic data are capable of resolving intra-basin structures in sufficient detail to allow prospective areas to be identified and for follow-up seismic surveys to be reliably planned.

  7. RIVERTON DOME GAS EXPLORATION AND STIMULATION TECHNOLOGY DEMONSTRATION, WIND RIVER BASIN, WYOMING

    SciTech Connect

    Dr. Ronald C. Surdam

    1999-08-01

    A primary objective of the Institute for Energy Research (IER)-Santa Fe Snyder Corporation DOE Riverton Dome project is to test the validity of a new conceptual model and resultant exploration paradigm for so-called ''basin center'' gas accumulations. This paradigm and derivative exploration strategy suggest that the two most important elements crucial to the development of prospects in the deep, gas-saturated portions of Rocky Mountain Laramide Basins (RMLB) are (1) the determination and, if possible, three-dimensional evaluation of the pressure boundary between normal and anomalous pressure regimes (i.e., this boundary is typically expressed as a significant inversion in both sonic and seismic velocity-depth profiles) , and (2) the detection and delineation of porosity/permeability ''sweet spots'' (i.e., areas of enhanced storage capacity and deliverability) in potential reservoir targets below this boundary. There are other critical aspects in searching for basin center gas accumulations, but completion of these two tasks is essential to the successful exploration for the unconventional gas resources present in anomalously pressured rock/fluid systems in the Rocky Mountain Laramide Basins. The southern Wind River Basin, in particular the Riverton Dome and Emigrant areas, is a neat location for testing this exploration paradigm. Preliminary work within the Wind River Basin has demonstrated that there is a regionally prominent pressure surface boundary that can be detected by inversions in sonic velocity depth gradients in individual well log profiles and that can be seen as a velocity inversion on seismic lines. Also, the Wind River Basin in general--and the Riverton Dome area specially--is characterized by a significant number of anomalously pressured gas accumulations. Most importantly, Santa Fe Snyder Corporation has provided the study with sonic logs, two 3-D seismic studies (40 mi{sup 2} and 30 mi {sup 2}) and a variety of other necessary geological and

  8. Petroleum geology of Cook Inlet Basin: an exploration model

    SciTech Connect

    Magoon, L.B.; Claypool, G.E.

    1981-06-01

    The potential of Cook Inlet for oil, evaluated with respect to the reservoir rocks encountered in the COST well and the relation of west-flank fields to the oil system, is discussed. The hydrocarbon potential is highest where Tertiary or Cretaceous reservoir rocks truncate Middle Jurassic source rocks. Several lines of evidence suggest that Middle Jurassic rocks are a possible source of all the commercially important oil in the Cook Inlet basin. Nonmarine Tertiary rocks are tentatively eliminated as possible oil source rocks because they are thermally immature and because they contain a coaly type of organic matter that does not yield liquid hydrocarbons efficiently upon pyrolysis. Cretaceous rocks are also tentatively eliminated as possible source rocks because of their inadequate organic richness and thermal immaturity. Only Middle Jurassic rocks contain adequate amounts of thermally mature, oil-prone organic matter and extractable hydrocarbons that both chemically and isotopically resemble Cook Inlet oil. The petroleum in west-flank oil fields first concentrated in a large stratigraphic trap in Tertiary rocks at the end of Miocene time. Pliocene and Pleistocene deformation caused secondary migration of this oil into present structural accumulations. (JMT)

  9. Exploring Sedimentary Basins with High Frequency Receiver Function: the Dublin Basin Case Study

    NASA Astrophysics Data System (ADS)

    Licciardi, A.; Piana Agostinetti, N.

    2015-12-01

    The Receiver Function (RF) method is a widely applied seismological tool for the imaging of crustal and lithospheric structures beneath a single seismic station with one to tens kilometers of vertical resolution. However, detailed information about the upper crust (0-10 km depth) can also be retrieved by increasing the frequency content of the analyzed RF data-set (with a vertical resolution lower than 0.5km). This information includes depth of velocity contrasts, S-wave velocities within layers, as well as presence and location of seismic anisotropy or dipping interfaces (e.g., induced by faulting) at depth. These observables provides valuable constraints on the structural settings and properties of sedimentary basins both for scientific and industrial applications. To test the RF capabilities for this high resolution application, six broadband seismic stations have been deployed across the southwestern margin of the Dublin Basin (DB), Ireland, whose geothermal potential has been investigated in the last few years. With an inter-station distance of about 1km, this closely spaced array has been designed to provide a clear picture of the structural transition between the margin and the inner portion of the basin. In this study, a Bayesian approach is used to retrieve the posterior probability distributions of S-wave velocity at depth beneath each seismic station. A multi-frequency RF data-set is analyzed and RF and curves of apparent velocity are jointly inverted to better constrain absolute velocity variations. A pseudo 2D section is built to observe the lateral changes in elastic properties across the margin of the basin with a focus in the shallow portion of the crust. Moreover, by means of the harmonic decomposition technique, the azimuthal variations in the RF data-set are isolated and interpreted in terms of anisotropy and dipping interfaces associated with the major fault system in the area. These results are compared with the available information from

  10. Deepwater exploration on tap in Voring Basin I area off Norway

    SciTech Connect

    Gading, M. )

    1994-11-07

    The results of IKU Petroleum Research studies support the assessment of considerable potential for the Voring Basin in the Norwegian Sea as a hydro-carbon province. Several critical factors concerning generation and preservation of hydrocarbons remain beyond the authors present understanding. Although some of these factors may be evaluated based on existing data, more firmly grounded results cannot be expected until exploration drilling begins. The paper describes the geologic history, hydrocarbon finds, and increased exploration activity in the area.

  11. Basin-mountain structures and hydrocarbon exploration potential of west Junggar orogen in China

    NASA Astrophysics Data System (ADS)

    Wu, X.; Qi, X.; Zheng, M.

    2015-12-01

    shows. Tacheng Basin, north faulted fold belt in the Heshituoluogai basin, and Hongyan fault bench zone in north Ulungur Depression in the Junggar Basin are promising areas for hydrocarbon exploration.

  12. Hydrodynamic analysis as an aid in exploration within mature basins: Examples from Sawtooth and Sunburst Reservoirs, northwestern Williston basin

    SciTech Connect

    Putnam, P.E.; Moore, S. ); Ward, G. )

    1990-05-01

    Linking hydrodynamics to detailed stratigraphic and structural analyses is a powerful tool in hydrocarbon exploration in mature basins, In southernmost Canada straddling the Alberta-Saskatchewan border, significant petroleum reserves are encountered within Mesozoic units which are largely controlled by subsurface flow cells. The Jurassic Sawtooth Formation is characterized by an eastward shift from lower shoreface quartzarenites to basinal coquinas. The Sawtooth is a blanket deposit and crops out along the flanks of several Tertiary uplifts in northern Montana. In the subsurface the Sawtooth is draped over several relatively young structures. Potentiometric mapping illustrates a northerly flow orientation within the Sawtooth, and oil pools under artesian conditions are located where flow paths cross steeply flanked structures. The Lower Cretaceous Sunburst Formation is a series of valley-fill sandstones with mainly southwesterly paleoflow orientations. Hydrocarbon pools (e.g., Manyberries field) are located within a regional potentiometric low formed by three converging cells which recharge in the south, northwest, and east. This potentiometric low is characterized by systematic changes in oil and water compositions, with progressively lighter oils and NaCl-rich waters found toward the low's center. Stratigraphic variability controls pooling within the low, with hydrocarbons located on the updip flanks of valley fills which border nonreservoir rocks. In the northwestern Williston basin regional hydrodynamic analysis, combined with standard subsurface approaches, allows operators to discern large new hydrocarbon-bearing trends within and between densely drilled areas characterized by complex structure and stratigraphy.

  13. 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: Chapter G.6 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Burruss, Robert A.; Ryder, Robert T.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    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.

  14. Cenozoic tectonic evolution and petroleum exploration in Perl River Mouth basin, South China Sea

    SciTech Connect

    Chi Yukun; Xu Shice )

    1990-06-01

    The Pearl River Mouth basin is a large Cenozoic continental margin basin that is rich in hydrocarbon potential. Fluvial-lake sequences were deposited before Oligocene, but all were covered by Miocene marine clastic and carbonate rocks. Both paleo-Pearl River delta system and reef/bank carbonate system were widely developed. At the early stage of the evolution, two subsidence belts and one uplift between them distributed in NE regional direction; grabens occurred in the north belt and depressions in the south belt. Tectonic movement was stronger in the east than the west. The main production zones have been drilled both in Miocene sandstone and carbonate rocks. As the exploration activities are developing, the basin will be one of the most significant China offshore oil production areas.

  15. Further evidence of a global carbon cycle disturbance at the Silurian-Devonian boundary: A study of the δ13C record in the eastern-most Central Appalachian Basin (Ulster County, New York)

    NASA Astrophysics Data System (ADS)

    Jost, A. B.; Gillikin, D. P.; Gröcke, D. R.

    2008-12-01

    The Silurian-Devonian (Pridoli-Lochkovian) boundary has been scrutinized and researched more than any other boundary worldwide, and within the last fifteen years, a large carbon isotope disturbance over the boundary has been noted in Europe, Australia, and parts of North America. In this study, a carbon isotope analysis across the Silurian-Devonian boundary in the upper Rondout/Lower Helderberg carbonate sequences of the eastern-most Appalachian Basin has revealed a +2.6 per mil excursion over the transition (approximately 5 m of material), suggesting that the S-D carbon cycle disturbances measured elsewhere are indeed related. δ13C values for the studied section range from +0.6 per mil to +4.8 per mil. Sampling has revealed some variability limited to and directly below the excursion, with values ranging from +2.4 per mil to +4.8 per mil. Following the excursion, δ13C values level off around +1.3 per mil, before gradually increasing to around +2.8 per mil. Samples were also analyzed for δ18O, but early diagenesis appears to have altered these values. Given the positive δ13C values, and correlation with sections from around the world, the carbon isotopes in these samples are thought to have remained unaffected by diagensis. Additionally, the discovery of the positive excursion (noted at two sites approximately 20 km apart) suggests that the S-D boundary exists within the Upper Thatcher/Lower Ravena members of the Manlius/Coeymans Formations of the Helderberg Group. Regional unconformities and limited biostratigraphic records have allowed the precise location of the boundary to remain debatable; however, the addition of chemostratigraphic evidence supports an Upper Thatcher/Lower Ravena location for the transition. Many studies hypothesize that the excursion is related to heightened surface water productivity following a rapid sea-level regression and increased input of phosphate into ocean waters. Understanding of the S-D event is critical in understanding the

  16. Basin-mountain structures and hydrocarbon exploration potential of west Junggar orogen in China

    NASA Astrophysics Data System (ADS)

    Wu, Xiaozhi; He, Dengfa; Qi, Xuefeng

    2016-04-01

    shows, and oil and gas fields have also been discovered in the Zaysan Basin in adjacent Kazakhstan and in adjacent Junggar, Tuha and Santanghu Basins. Drilling data, geochemical analysis of outcrop data, and the disection of ancient Bulongguoer oil reservoir at the south margin of the Hefeng Basin show there developed two sets of good transitional source rocks, the lower Hujierste Formation in the Middle Devonian (D2h1) and the Hebukehe Formation in the Upper Devonian and Lower Carboniferous (D3-C1h) in this area, which, 10 to 300 m thick, mainly distribute in the shoal water zone along Tacheng-Ertai Late Paleozoic island arc belt. Reservoirs were mainly formed in the Jurassic and then adjusted in two periods, one from the end of the Jurassic to middle Cretaceous and the other in early Paleogene. Those early oil reservoirs might be destroyed in areas such as Bulongguoer with poor preservation conditions, but in an area with good geologic and preserving conditions, oil and gas might accumulate again to form new reservoirs. Therefore, a potential Middle Devonian-Lower Carboniferous petroleum system may exist in Tacheng-Ertai island arc belt, which may become a new domain for exploration, north faulted fold belt in the Heshituoluogai basin, and Hongyan fault bench zone in north Ulungur Depression in the Junggar Basin are promising areas for hydrocarbon exploration.

  17. RIVERTON DOME GAS EXPLORATION AND STIMULATION TECHNOLOGY DEMONSTRATION, WIND RIVER BASIN, WYOMING

    SciTech Connect

    Ronald C. Surdam; Zunsheng Jiao; Nicholas K. Boyd

    1999-11-01

    The new exploration technology for basin center gas accumulations developed by R.C. Surdam and Associates at the Institute for Energy Research, University of Wyoming, was applied to the Riverton Dome 3-D seismic area. Application of the technology resulted in the development of important new exploration leads in the Frontier, Muddy, and Nugget formations. The new leads are adjacent to a major north-south trending fault, which is downdip from the crest of the major structure in the area. In a blind test, the drilling results from six new Muddy test wells were accurately predicted. The initial production values, IP, for the six test wells ranged from < one mmcf/day to four mmcf/day. The three wells with the highest IP values (i.e., three to four mmcf/day) were drilled into an intense velocity anomaly (i.e., anomalously slow velocities). The well drilled at the end of the velocity anomaly had an IP value of one mmcf/day, and the two wells drilled outside of the velocity anomaly had IP values of < one mmcf/day and are presently shut in. Based on these test results, it is concluded that the new IER exploration strategy for detecting and delineating commercial, anomalously pressured gas accumulation is valid in the southwestern portions of the Wind River Basin, and can be utilized to significantly reduce exploration risk and to increase profitability of so-called basin center gas accumulations.

  18. High resolution temperature models for geothermal exploration in sedimentary basins: methods and applications

    NASA Astrophysics Data System (ADS)

    van Wees, Jan-Diederik; Bonte, Damien; Verweij, Hanneke; Kramers, Leslie

    2010-05-01

    Key to geothermal exploration success is sufficiently high temperature. This paper focusses on high resolution temperature prediction for geothermal exploration in sedimentary basins. In existing thermal basin models for oil and gas exploration, the focus is on predicting past temperature histories in the sedimentary cover for assessment of oil and gas maturation and expulsion. For detailed 3D models (i.e. involving millions of temperature nodes) these models take long to run and are hard to calibrate to both temperature data in wells and lithosphere boundary conditions. Moreover, spatial variations in basal heat flow is generally not controlled by tectonic boundary conditions. Tectonic models, capable of modelling the thermal consequences of basin evolution, allow to asses spatial heat flow variability based on lithosphere deformation, and provide additional constraints and better quantitative understanding of temperature anomalies. In order to improve modeling capability in terms of model resolution and incorporating tectonic effects, we have developed a novel 3D thermal basin model. In the model transient temperatures are calculated over the last 20 Million years for a 3D heat equation on a regular 3D finite difference grid, allowing for spatial variation in thermal properties, temporal variation in surface temperature and spatial and temporal variations in basal heat flow. Furthermore the model takes into account heat advection, including effects of sedimentation, and lithosphere deformation. The model is iteratively calibrated to temperature data at the well locations, typically taking less than 5 runs. In addition well locations basal heat flow conditions are interpolated based on tectonic constraints. The capabilities of the model are demonstrated for various sedimentary basins, including the Netherlands. The models have been calibrated to extensive well data, showing considerable spatial variability which appears to be related to both tectonic variation as

  19. Perspectives on Physical Activity and Exercise Among Appalachian Youth

    PubMed Central

    Swanson, Mark; Schoenberg, Nancy E.; Erwin, Heather; Davis, Rian E.

    2015-01-01

    Background Most children in the United States receive far less physical activity (PA) than is optimal. In rural, under resourced areas of Appalachian Kentucky, physical inactivity rates are significantly higher than national levels. We sought to understand children’s perceptions of PA, with the goal of developing culturally appropriate programming to increase PA. Methods During 11 focus groups, we explored perspectives on PA among 63 Appalachian children, ages 8–17. Sessions were tape recorded, transcribed, content analyzed, and subjected to verification procedures. Results Several perspectives on PA emerged among these rural Appalachian youth, including the clear distinction between PA (viewed as positive) and exercise (viewed as negative) and an emphasis on time and resource factors as barriers to adequate PA. Additional PA determinants expressed in the focus groups are similar to those of other populations. We include children’s recommendations for appealing PA programs. Conclusions Appalachian and other rural residents contend with the loss of rural health advantages (due to declines in farming/other occupational and avocational transitions). At the same time, Appalachian residents have not benefitted from urban PA facilitators (sidewalks, recreational facilities, clubs and organized leisure activities). Addressing low PA levels requires extensive community input and creative programming. PMID:22397810

  20. Application of sequence stratigraphy to oil and gas exploration in Bredasdorp basin offshore South Africa

    SciTech Connect

    Van Wyk, N.J.S.

    1989-03-01

    For more than two decades, oil and gas exploration in offshore South African rift basins within structural synrift plays yielded limited success. After the first oil discovery in postrift sediments in the Bredasdorp basin in 1987, sequence-stratigraphic concepts were applied to the Lower Cretaceous postrift sequences to permit correlation of depositional systems tracts and related facies throughout the basin. Extensive high-resolution seismic coverage and borehole control supported the study. The interplay of diminishing rift tectonics, thermal cooling, and inferred eustatic variations in global sea level produced a distinctive series of repetitive cycle depositional sequences. As many as 10 cyclic sequences and megasequences, deposited between the mid-Valanginian and lower Santonian, can be recognized within resolution limits of regional seismic profiles. Various elements of lowstand systems tracts within these sequences appear to contain potential reservoirs. Highly erosional (type 1) unconformities, commonly exhibiting incised valleys and canyons, provide surfaces on which (1) mounded and sheetlike submarine/basin-floor fans, (2) submarine channel fill and associated mounds and fans, and (3) prograding deltaic/coastal lowstand wedges were deposited. These fans, channel fills, and wedges are top sealed and sourced by transgressive shales and marine condensed sections, deposited at a time of regional transgression of the shoreline. One discovery well and various reservoir-quality sandstones occurring at predicted stratigraphic levels in other wells support the application of the sequence-stratigraphic concepts to hydrocarbon exploration.

  1. Middle Ordovician carbonate ramp deposits of central Appalachians

    SciTech Connect

    Demicco, R.V.

    1986-05-01

    Middle Ordovician carbonates exposed in Maryland and Pennsylvania can be divided into six facies, each a few tens to hundreds of meters thick: (1) cyclic, meter-scale, alternating thin-bedded to massive limestones and mud-cracked, stromatolitic laminites; (2) thick-bedded to massive skeletal wackestones containing diverse fauna; (3) cross-stratified skeletal-oncoid grainstones; (4) graded, thin-bedded limestones with diverse fauna and internal planar lamination or hummocky cross-stratification; (5) nodular, thin-bedded limestones; and (6) shaly, thin-bedded to laminated limestones containing rare breccia beds. These facies are interpreted as deposits of: (1) tidal flats; (2) open, bioturbated muddy shelf; (3) lime-sand shoals; (4) below normal wave-base shelf; (5) deep ramp; and (6) basin. Palinspastic reconstructions of facies distribution in Maryland and Pennsylvania suggest that these facies developed during flooding of a carbonate ramp that deepened northeastward into a foreland basin. This northern depocenter of the Middle Ordovician Appalachian foreland basin is notably different that its southern counterpart in Virginia and Tennessee. Large skeletal bioherms did not develop on the northern carbonate ramp, where only one onlap package exists. Thus, although the record of the foundering of the passive Cambrian-Ordovician carbonate shelf is grossly similar in the southern and central Appalachians, there are several significant differences. The overlying Martinsburg Formation contains deep-water facies and taconic-style thrust sheets in the central Appalachians, which suggests that the two depocenters may have had different tectonic settings.

  2. Timing of Mississippi Valley-type mineralization: Relation to Appalachian orogenic events

    SciTech Connect

    Kesler, S.E.; van der Pluijm, B.A. )

    1990-11-01

    Although Mississippi Valley-type deposits in Lower Ordovician carbonate rocks of the Appalachian orogen are commonly interpreted to have been precipitated by basinal brines, the timing of brine migration remains poorly known. Late Paleozoic K-Ar isotopic ages on authigenic K-feldspar, which is widespread in Appalachian carbonate rocks, as well as evidence of paleomagnetic overprints of similar age, have focused attention on the possibility that these Mississippi Valley-type deposits formed as a result of late Paleozoic deformation. Geologic and geochemical similarities among most of these deposits, from Georgia to Newfoundland, including unusually high sphalerite/galena ratios, isotopically heavy sulfur, and relatively nonradiogenic lead, suggest that they are coeval. Sphalerite sand that parallels host-rock layering in many of the deposits indicates that mineralization occurred before regional deformation. Although the late Paleozoic age of deformation in the southern Appalachians provides little constraint on the age of Mississippi Valley-type mineralization, deformation of these deposits in the Newfoundland Appalachians is early to middle Paleozoic in age. Thus, if Ordovician-hosted, Appalachian Mississippi Valley-type deposits are coeval, they must have formed by middle Paleozoic time and cannot be the product of a late Paleozoic fluid-expulsion event. This hypothesis has important implications for basin evolution, fluid events, and remagnetization in the Appalachians.

  3. Characterization of Appalachian faults

    SciTech Connect

    Hatcher, R.D. Jr.; Odom, A.L.; Engelder, T.; Dunn, D.E.; Wise, D.U.; Geiser, P.A.; Schamel, S.; Kish, S.A.

    1988-02-01

    This study presents a classification/characterization of Appalachian faults. Characterization factors include timing of movement relative to folding, metamorphism, and plutonism; tectonic position in the orogen; relations to existing anisotropies in the rock masses; involvement of particular rock units and their ages, as well as the standard Andersonian distinctions. Categories include faults with demonstrable Cenozoic activity, wildflysch-associated thrusts, foreland bedding-plane thrusts, premetamorphic to synmetamorphic thrusts in medium- to high-grade terranes, postmetamorphic thrusts in medium- to high-grade terranes, thrusts rooted in Precambrian basement, reverse faults, strike-slip faults, normal (block) faults, compound faults, structural lineaments, faults associated with local centers of disturbance, and geomorphic (nontectonic) faults.

  4. Riverton Dome Gas Exploration and Stimulation Technology Demonstration, Wind River Basin, Wyoming

    SciTech Connect

    Ronald C. Surdam

    1998-11-15

    This project will provide a full demonstration of an entirely new package of exploration technologies that will result in the discovery and development of significant new gas reserves now trapped in unconventional low-permeability reservoirs. This demonstration includes the field application of these technologies, prospect definition and well siting, and a test of this new strategy through wildcat drilling. In addition this project includes a demonstration of a new stimulation technology that will improve completion success in these unconventional low permeability reservoirs which are sensitive to drilling and completion damage. The work includes two test wells to be drilled by Snyder Oil Company on the Shoshone/Arapahoe Tribal Lands in the Wind River Basin. This basin is a foreland basin whose petroleum systems include Paleozoic and Cretaceous source beds and reservoirs which were buried, folded by Laramide compressional folding, and subsequently uplifted asymmetrically. The anomalous pressure boundary is also asymmetric, following differential uplift trends. The Institute for Energy Research has taken a unique approach to building a new exploration strategy for low-permeability gas accumulations in basins characterized by anomalously pressured, compartmentalized gas accumulations. Key to this approach is the determination and three-dimensional evaluation of the pressure boundary between normal and anomalous pressure regimes, and the detection and delineation of areas of enhanced storage capacity and deliverability below this boundary. This new exploration strategy will be demonstrated in the Riverton Dome� Emigrant Demonstration Project (RDEDP) by completing the following tasks: 1) detect and delineate the anomalous pressure boundaries, 2) delineate surface lineaments, fracture and fault distribution, spacing, and orientation through remote sensing investigations, 3) characterize the internal structure of the anomalous pressured volume in the RDEDP and

  5. Characteristics of discrete and basin-centered parts of the Lower Silurian regional oil and gas accumulation, Appalachian basin; preliminary results from a data set of 25 oil and gas fields

    USGS Publications Warehouse

    Ryder, Robert T.

    1998-01-01

    Oil and gas trapped in Lower Silurian 'Clinton' sands and Medina Group sandstone constitute a regional hydrocarbon accumulation that extends 425 mi in length from Ontario, Canada to northeastern Kentucky. The 125-mi width of the accumulation extends from central Ohio eastward to western Pennsylvania and west-central New York. Lenticular and intertonguing reservoirs, a gradual eastward decrease in reservoir porosity and permeability, and poorly segregated gas, oil, and water in the reservoirs make it very difficult to recognize clear-cut geologic- and production-based subdivisions in the accumulation that are relevant to resource assessment. However, subtle variations are recognizable that permit the regional accumulation to be subdivided into three tentative parts: a western gas-bearing part having more or less discrete fields; an eastern gas-bearing part having many characteristics of a basin-centered accumulation; and a central oil- and gas-bearing part with 'hybrid' fields that share characteristics of both discrete and basin-centered accumulation. A data set of 25 oil and gas fields is used in the report to compare selected attributes of the three parts of the regional accumulation. A fourth part of the regional accumulation, not discussed here, is an eastern extension of basin-centered accumulation having local commercial gas in the Tuscarora Sandstone, a proximal facies of the Lower Silurian depositional system. A basin-centered gas accumulation is a regionally extensive and commonly very thick zone of gas saturation that occurs in low-permeability rocks in the central, deeper part of a sedimentary basin. Another commonly used term for this type of accumulation is deep-basin gas accumulation. Basin-centered accumulation is a variety of continuous-type accumulation. The 'Clinton' sands and Medina Group sandstone part of the basin-centered gas accumulation is characterized by: a) reservoir porosity ranging from about 5 to 10 percent; b) reservoir permeability

  6. Geology of the Southern Appalachian Mountains

    USGS Publications Warehouse

    Clark, Sandra H.B.

    2008-01-01

    The Southern Appalachian Mountains includes the Blue Ridge province and parts of four other physiographic provinces. The Blue Ridge physiographic province is a high, mountainous area bounded by several named mountain ranges (including the Unaka Mountains and the Great Smoky Mountains) to the northwest, and the Blue Ridge Mountains to the southeast. Metamorphic rocks of the mountains include (1) fragments of a billion-year-old supercontinent, (2) thick sequences of sedimentary rock that were deposited in subsiding (sinking) basins on the continent, (3) sedimentary and volcanic rocks that were deposited on the sea floor, and (4) fragments of oceanic crust. Most of the rocks formed as sediments or volcanic rocks on ocean floors, islands, and continental plates; igneous rocks formed when crustal plates collided, beginning about 450 million years ago. The collision between the ancestral North American and African continental plates ended about 270 million years ago. Then, the continents began to be stretched, which caused fractures to open in places throughout the crust; these fractures were later filled with sediment. This product (U.S. Geological Survey Scientific Investigations Map 2830) consists of a geologic map of the Southern Appalachian Mountains overlain on a shaded-relief background. The map area includes parts of southern Virginia, eastern West Virginia and Tennessee, western North and South Carolina, northern Georgia and northeastern Alabama. Photographs of localities where geologic features of interest can be seen accompany the map. Diagrams show how the movement of continental plates over many millions of years affected the landscapes seen today, show how folds and faults form, describe important mineral resources of the region, and illustrate geologic time. This two-sided map is folded into a convenient size (5x9.4 inches) for use in the field. The target audience is high school to college earth science and geology teachers and students; staffs of

  7. Application of seismic sequence concepts to basin evolution and petroleum exploration, Pletmos basin, offshore South Africa

    SciTech Connect

    Keenan, J.H.G. )

    1989-03-01

    As a result of excellent seismic data, shallow burial depths, and slow subsidence rates, 67 type 1 and type 2 unconformities were identified in the postrift Cretaceous section of the Pletmos subbasins. The purpose of this study was to develop a seismic sequence-stratigraphic framework for the mid-Valanginian to mid-Campanian sequences as a basis for future petroleum exploration. The study further developed the recent stratigraphic techniques proposed by Exxon. Sixteen of the 67 type 1 and type 2 unconformities could be correlated directly with Exxon's global third-order cycles; the remaining 51, interpreted to be fourth- and fifth-order cycles, could be grouped into megasequences comprising 2 to 6 sequences, bounded by major third-order type 1 unconformities. The study demonstrates the complex interplay of variations in sea level fluctuation, differential subsidence rates, sediment supply, and tectonic stability and the resultant wide range of geometries and styles in depositional environments. By using seismic sequence concepts, these variables can be accounted for and can be made with greater assurance. Further analyses of lowstand systems tracts are underway to localize stratigraphic trap prospects to be drilled in the near future.

  8. Determination of organic-matter content of Appalachian Devonian shales from gamma-ray logs.

    USGS Publications Warehouse

    Schmoker, J.W.

    1981-01-01

    The organic-matter content of the Devonian shale of the Appalachian basin is important for assessing natural-gas resources. In most of the western part of the Appalachian basin the organic-matter content of the Devonian shale can be estimated from gamma-ray wire-line logs. Organic-matter contents estimated using these logs are compared with determinations from direct laboratory analyses of organic carbon for 74 intervals of varying thickness from 12 widely separated wells. The cumulative pool of gamma-ray logs for the Devonian shale forms a large and geographically broad data base. The approach may also be applicable to other formations.-from Author

  9. White Infant Mortality in Appalachian States, 1976-1980 and 1996-2000: Changing Patterns and Persistent Disparities

    ERIC Educational Resources Information Center

    Yao, Nengliang; Matthews, Stephen A.; Hillemeier, Marianne M.

    2012-01-01

    Purpose: Appalachian counties have historically had elevated infant mortality rates. Changes in infant mortality disparities over time in Appalachia are not well-understood. This study explores spatial inequalities in white infant mortality rates over time in the 13 Appalachian states, comparing counties in Appalachia with non-Appalachian…

  10. Prospects for hydrocarbon exploration in the Mesozoic and Paleozoic sections of the Pannonian basin in Hungary

    SciTech Connect

    Mattick, R. ); Koncz, I.; Bardocz, B.; Szalay, A.; Szent-Gyoergyi, K. ); Csaszar, G.; Juhasz, E. )

    1993-09-01

    To date, exploration in the Pannonian basin of Hungary has concentrated on oil and gas believed to be derived from source rocks of the Cenozoic. In this sense, the basin is a mature hydrocarbon province. However, exploration of the Mesozoic and Paleozoic sections has just begun. These section may contain significant quantities of hydrocarbons derived from source rocks of the Mesozoic. Much of the buried basement consists of a complex system of stacked nappes composed of Mesozoic and older rocks. Basement structures from three areas are shown: (1) southwestern Hungary, where oil and gas produced from fracture zones in the crest of nappes; (2) southeastern Hungary, where thrusting occurred subsequent to Upper Cretaceous deposition; and (3) western Hungary, where thrusting occurred prior to Upper Cretaceous deposition. In general, Paleozoic-Middle Triassic rocks are overmature; however, Upper Triassic-Cretaceous rocks entered the oil-generation window during the Neogene. The heavy oils of the Zala basin were generated from organic-rich marls of the Late Triassic. In the Mecsek area, Toarcian shales are likely a good source for oil. Upper Cretaceous rocks, because of their terrestrial character, are inferred to be gas prone. Reservoir properties of Triassic and older rocks are expected to be poor, except where fracture porosity occurs. In the Nagylengyel field, rudist limestones of Late Cretaceous contain prolific reservoirs with primary solution and fracture porosity. Although the average porosities of these reservoir rocks are relatively low (2-4%), permeabilities are >1-2 d as a result of paleokarst development.

  11. Quantitative paleogeography and accretionary history, northern Appalachians

    SciTech Connect

    Pluijm, B.A. van der; Voo, R. van der . Dept. of Geological Sciences)

    1992-01-01

    Ongoing paleomagnetic work on Early and Middle Paleozoic units provides quantitative data on paleogeography, latitudinal separation and latitudinal drift rates of tectonic elements that characterize the history of the northern segment of the Appalachian orogen. Following rifting and opening of Iapetus, the southern margin of Laurentia moved from ca 15S in the Ordovician to ca. 30S in the late Silurian: the northern margin of Avalon drifted northward (separate from Gondwana) from > 50--30S during the same time interval. Paleolatitudes from volcanic units of the intervening Central Mobile Belt that yield primary magnetizations are: Newfoundland: Ordovician arc-back arc basin: 11[degree]S; Ordovician ocean island/arc: 31[degree]S; Silurian continental cover: Botwood Gp: 24[degree]S, Springdale Gp: 17[degree]S New Brunswick: Ordovician rift-subduction complex: 53[degree]S. Maine: Munsungun Volcanic Terrane 18[degree]S; Winterville Volcanic Terrane 15--20[degree]S; upper part Lunksoos Composite Terrane: 20[degree]S. The Ordovician results indicate several near-Laurentian volcanic terranes and back-arc basins, landward-dipping subduction complexes on opposite margins of Iapetus, and intra-Iapetus ocean islands/arcs. Silurian paleogeographic and tectonostratigraphic data show that closure of Iapetus and progressive outboard accretion in the northern portion of the Appalachian orogen was complete by the late Silurian. This closure is accompanied by considerable Ordovician to Early Silurian left-lateral strike slip and subsequent right-lateral displacement based on the relative positions of Laurentia, Avalon and Gondwana in Early and Middle Paleozoic times.

  12. Down Home, Downtown: Urban Appalachians Today.

    ERIC Educational Resources Information Center

    Obermiller, Phillip J., Ed.

    This book contains selected presentations from a conference on urban Appalachians held in Cincinnati, Ohio, in September 1995. The papers present diverse perspectives on the migration from rural Appalachia to industrial centers, questions of Appalachian culture and identity, community development in Appalachian neighborhoods, and rural Appalachian…

  13. Appalachian Regional Commission: 1986 Annual Report.

    ERIC Educational Resources Information Center

    Russell, Jack, Ed.; And Others

    The Appalachian Regional Commission used its $120 million appropriation for fiscal year 1986 to create and retain jobs under the jobs and private investment program, provide basic public facilities to the worst-off Appalachian counties under the distressed counties program, and to work toward closing the gaps in the Appalachian Development Highway…

  14. Exploration of a lignite-bearing basin in Northern Ireland using ground magnetic and VLF-EM methods

    SciTech Connect

    McCaffrey, R.J.; McElroy, W.J.; Leslie, A.G.

    1995-03-01

    In an exploration technique feasibility study, a detailed magnetic and VLF-EM survey was carried out on the poorly exposed, lignite-bearing Crumlin subbasin within the Lough Neagh Basin, Co. Antrim, Northern Ireland. The faulted and onlapped margins of the basin, as well as lithological units and structures within the basin, were delineated by simple processing techniques applied to the data. The combination of the two methods overcomes the limitations of each method when it is used alone. These techniques could be successfully applied to other lignite-bearing basins sited on strongly magnetic basement worldwide.

  15. Geology of oil fields and future exploration potential in west African Aptian Salt basin

    SciTech Connect

    Bignell, R.D.; Edwards, A.D.

    1987-05-01

    The Aptian Salt basin of west Africa, extends from Equatorial Guinea southward to Angola, contains recoverable reserves estimated at nearly 4 billion BOE, and is current producing 600,000 BOPD. The basin developed as a result of tensional forces between west Africa and South America initiated at the end of the Jurassic. The prospective sedimentary sequences ranged in age from Early Cretaceous (uppermost Jurassic in places) to Holocene and is divided by the Aptian transgressive sand and salt into a pre-salt, nonmarine, syn-rift sequence and a post-salt, marine, post-rift sequence. Both the pre- and post-salt sequences contain several successful exploration plays, the most prolific of which are the Early Cretaceous nonmarine sandstone fields in tilted fault blocks of Gabon and Cabinda; Early Cretaceous carbonate buildups on the margins of basement highs in Cabinda; Early Cretaceous transgressive marine sandstone fields in anticlines draped over basement highs in Gabon; Late Cretaceous shallow marine sandstone and carbonate fields in salt-related structures in the Congo, Zaire, Cabinda, and Angola; Late Cretaceous dolomites in structural/stratigraphic traps in Angola; Late Cretaceous/early Tertiary deltaic/estuarine sandstone traps formed by salt movement in Gabon, Cabinda, and angola; and Tertiary marine turbidite fields in Cabinda and Angola. Despite the exploration success in these trends, much of the basin is under or poorly explored. The major problems for exploration are the poor quality of seismic definition beneath the salt, which makes it difficult to predict pre-salt structure and stratigraphy, and the importance of a stratigraphic element in many of the post-salt traps, also difficult to detect on seismic.

  16. Spirituality and its relationships with the health and illness of Appalachian people.

    PubMed

    Diddle, Gina; Denham, Sharon A

    2010-04-01

    This article explores the ways spirituality intertwines with the health and culture of those living in the Appalachian region. Nursing has long considered the value of spirituality and faith, noting its complex connections with health and illness. Literature pertaining to spirituality, health, and the culture of those residing in the Appalachian region was reviewed. Although the review suggests that connections between spirituality and health exist, empirical evidence is limited, somewhat dated, and lacks viable conclusions relative to the diverse needs of the Appalachian population. Focused research that addresses strongly linked operationally defined variables is needed to strengthen the evidence for clarity about distinct applications to practice.

  17. Paleogene turbidite system in the Maracaibo basin: A new exploration frontier

    SciTech Connect

    Zambrano, E.; Melendiez, L.; Ghosh, S.

    1996-08-01

    Regional sequence stratigraphic analysis revealed the presence of Paleocene(?)-Lower Eocene lowstand turbiditic deposits in Maracaibo Basin. The emplacements of the Lara nappes on the north during late Paleocene triggered the development of a foredeep in the northeastern part of the Maracaibo Basin. During the ensuing lowstand stage, siliciclastic sediments poured into the foredeep principally from the southwest, and secondarily from the Merida and Banbacoas highs; olistoliths and argillaceous sediments could have come from the north. These sediments were deposited as lowstand prograding wedge (slopefan complex) and submarine fan lobes in a belt trending northwest-southeast beyond the eastern shore of the present day Lake Maracaibo. The slope-fan complex consists of stacked progradational clinoforms with toesets of shingled turbidites. The exploratory potential of the slope-fan complex is still under study. Basinward the slope-fan facies grades into a thick, mappable and convex submarine fan lobe (Basin Floor Fan) overlying Paleocene strata. Farther eastward of this subsurface turbidite complex, extensive outcrops of coeval turbidites of the Trujillo-Rancheria formations occur in the Serrania de Trujillo. The subsurface shelf-fed turbidite complex, as yet untested, may be of considerable economic interest as the potential fan lobe trap overlies the rich La Luna Eocene kitchen. Oil generation was relatively early (Middle Eocene) in this part of the basin. Early hydrocarbon generation and migration along vertical/subvertical faults would have filled the trap and preserved the porosity from destructive diagenesis. If hydrocarbons are present, this area may well become the new exploration frontier of the Maracaibo Basin.

  18. Application of Landsat imagery to hydrocarbon exploration in Niobrara Formation, Denver basin

    SciTech Connect

    Merin, I.S.; Moore, W.R.

    1985-02-01

    The Niobrara Formation produces commercial quantities of oil from fractures in several places in the Denver basin. The Niobrara in this basin is an oil-prone, mature source rock having as much as 3.4% TOC, and has been in the generating window since early Eocene. This implies that hydrocarbon generation from the Niobrara is partly contemporaneous with the Laramide orogeny. The Laramide was a multiple-phase orogenic event that began with compression directed to the east-northeast during the Late Cretaceous to Paleocene and ended with compression directed to the northeast during the Eocene. The authors believe the Eocene phase activated northeast-trending extension fractures that may have acted as loci for storage and migration of hydrocarbons, locally generated in the Niobrara. The auto-fracing pressures related to hydrocarbon generation in the Niobrara theoretically would preferentially open and fill this northeast-trending fracture system. Examination of Landsat imagery shows that zones of northeast-trending lineaments are present throughout the basin. Numerous northeast-trending faults are present in the basin, and many overlie older zones that were reactivated during the Laramide. This suggests that these lineaments are previously unrecognized fracture zones. The authors have defined an exploration fairway within the basin based on subsurface isopach and resistivity mapping. The authors believe that mapping of northeast-trending fractures can help identify leads (within this fairway) prospective for Niobrara production. Support of this concept is the location of several apparently productive Niobrara wells along a zone of northeast-trending lineaments.

  19. Exploring Unconventional Hydrocarbons in the Makó Trough, Pannonian basin, Hungary: Results and Challenges

    NASA Astrophysics Data System (ADS)

    Horvath, Anita; Bada, Gabor; Szafian, Peter; Sztano, Orsolya; Law, Ben; Wallis, Rod

    2010-05-01

    The latest phase exploration in the Makó Trough, which commenced a few years ago, has focused on the utilization of unconventional hydrocarbons. Accumulations are regarded as "unconventional" when they cannot be produced economically except by means of some sort of stimulation, usually hydraulic fracturing. The model we have developed for the evaluation of the hydrocarbon potential indicates a significant gas accumulation in the area of the Makó Trough. The tally of the distinctive attributes of the hydrocarbon system and the combined analysis of the available geological data led to the conclusion that the Makó Trough represents an area of active basin-centered gas accumulation (BCGA), with very significant perspective reserves. In a BCGA, hydrocarbons do not accumulate conventionally, in structural or stratigraphic traps, but rather in cells. Due to the geological setting of the Makó Trough, the hydrocarbon cell here forms a relatively continuous zone marked by considerable internal lithological and petrophysical variability. The most prolific parts, called sweet spots, possess a reservoir potential higher than the average. The identification of these sweet spots constitutes one of the most important, and quite possibly the most challenging task of the entire exploration project. The hemipelagic Endrőd Formation, which acts as the source rock, contains organic-rich marls in a depth delimited by the 170-230 °C isotherms. These marls constitute the still active hydrocarbon "kitchen" of the BCGA in the Makó Trough. The top and bottom boundaries of the cell essentially coincide with the turbidites of the Szolnok Formation and the top of the pre-Neogene basement, respectively. In light of the fact that pressure, temperature, and maturity tests have produced rather similar results in a number of wells in the area, we have reason to believe that the extension of the Makó Trough's BCGA is of regional dimensions (>1000 km2). The thickness and lateral extension of

  20. Aspects of exploration, development of Vulcan sub-basin, Timor Sea

    SciTech Connect

    Smith, B.L. ); Lawrence, R.B. )

    1989-10-01

    This article presents a geological summary of the Vulcan sub-basin. Three exploratory phases in the Timor Sea are detailed and the economics of exploration in this area is discussed. The Timor Sea is emerging as a major Australian oil-producing area. From the Jabiru field alone Timor Sea oil production contributes 9% of Australia's oil production. The Timor Sea will soon rank second in terms of daily production. Early phases of exploration in the area focused on the detection and drilling of large structures. Success rates were low. Since the Jabiru discovery in 1983, better exploration methods have resulted in the delineation of many prospects which could contain significant oil reserves. New play concepts being developed will result in additional prospects.

  1. Evolution of Cambrian-Ordovician carbonate shelf, US Appalachians

    SciTech Connect

    Read, J.F.

    1985-01-01

    Newly compiled cross sections and isopach maps of the Cambro-Ordovician continental shelf, U.S. Appalachians shows that thickness and facies trends are controlled by the Adirondack, New Jersey and Virginia and Alabama arches, and depocenters in Tennessee, Pennsylvania and the Rome Trough. Carbonate sedimentation was initiated with drowning of Early Cambrian clastics, deposition of carbonate ramp facies followed by drowning, regional regression and deposition of Early to Middle Cambrian red beds and platform margin rimmed shelf lime sands and reefs. During subsequent regional transgression the Conasauga intrashelf shale basin formed, bounded toward the shelf edge and along depositional strike by Middle to Upper Cambrian oolitic ramp facies and cyclic peritidal carbonates. During Middle Cambrian rifting, the Rome Trough was filled by thick clastics and carbonates. Intrashelf basin filling and regional regression caused progradation of Late Cambrian cyclic carbonates and clastics across the shelf. By this time, the margin had a relief of 2.5 kms. During the Early Ordovician, incipient drowning of the shelf formed subtidal carbonates and bioherms that passed up into cyclic carbonates which grade seaward into lime sands and reefs. Numerous unconformities interrupt this sequence in the Northern Appalachians. Early dolomitization patterns were controlled by regional highs. Subsidence rates on the margin were low (4 cm/1000 yrs) and typical of a mature passive margin. Shelf sedimentation in the Southern Appalachians ceased with arc-continent collision and development of the Knox unconformity, which dies out into the Pennsylvania depocenter.

  2. Correlation chart of Pennsylvanian rocks in Alabama, Tennessee, Kentucky, Virginia, West Virginia, Ohio, Maryland, and Pennsylvania showing approximate position of coal beds, coal zones, and key stratigraphic units: Chapter D.2 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    USGS Publications Warehouse

    Ruppert, Leslie F.; Trippi, Michael H.; Slucher, Ernie R.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    Because of the many names used to identify individual coal beds and coal zones in the historic Appalachian basin coal-mining districts, coal bed designations may differ even more than stratigraphic nomenclature. In eastern Kentucky, northwest of the Pine Mountain thrust fault on the Cumberland overthrust sheet, for example, coal beds or coal zones equivalent to the Lower Elkhorn coal zone (within the Pikeville Formation) are identified also as the Eagle coal zone, Pond Creek coal zone, and Blue Gem coal bed (fig. 1). Southeast of the Pine Mountain thrust fault, yet still in Kentucky, equivalent coals in this same interval are known as the Imboden and Rich Mountain. Moreover, this same interval of coal is identified as the Blue Gem coal in Tennessee, the Imboden coal bed or Campbell Creek or Pond Creek coal zones in Virginia, and the Eagle coal zone in West Virginia.

  3. ERRSAC contributions to the search for Appalachian hydrocarbons

    NASA Technical Reports Server (NTRS)

    Blodget, H. W.

    1981-01-01

    The utility of lineaments identified on LANDSAT imagery as an exploration tool in the search for hydrocarbons within three Appalachian test sites were assessed. The optimum LANDSAT imagery enhancement technique for displaying lineaments was identified. The LANDSAT lineament data were analyzed and results were correlated with oil and gas field information for each of three tests sites. Good correlations were found for several states. Successful techniques can be incorporated into a broader exploration model.

  4. Coalbed methane production potential in U. S. basins

    SciTech Connect

    Byer, C.W.; Mroz, T.H.; Covatch, G.L.

    1987-07-01

    The major emphasis of the U.S. DOE's coalbed methane research has been on estimating the magnitude of the resource and developing systems for recovery. Methane resource estimates for 16 basins show that the greatest potential is in the Piceance, Northern Appalachian, Central Appalachian, Powder River, and Greater Green River coal basins. Small, high-potential target areas have been selected for in-depth analysis of the resource. Industry interest is greatest in the Warrior, San Juan, Piceance, Raton Mesa, and Northern and Central Appalachian basins. Production curves for several coalbed methane wells in these basins are included.

  5. Constraining stress magnitudes using petroleum exploration data in the Cooper Eromanga Basins, Australia

    NASA Astrophysics Data System (ADS)

    Reynolds, Scott D.; Mildren, Scott D.; Hillis, Richard R.; Meyer, Jeremy J.

    2006-03-01

    The magnitude of the in situ stresses in the Cooper-Eromanga Basins have been determined using an extensive petroleum exploration database from over 40 years of drilling. The magnitude of the vertical stress ( Sv) was calculated based on density and velocity checkshot data in 24 wells. Upper and lower bound values of the vertical stress magnitude are approximated by Sv = (14.39 × Z) 1.12 and Sv = (11.67 × Z) 1.15 functions respectively (where Z is depth in km and Sv is in MPa). Leak-off test data from the two basins constrain the lower bound estimate for the minimum horizontal stress ( Shmin) magnitude to 15.5 MPa/km. Closure pressures from a large number of minifrac tests indicate considerable scatter in the minimum horizontal stress magnitude, with values approaching the magnitude of the vertical stress in some areas. The magnitude of the maximum horizontal stress ( SHmax) was constrained by the frictional limits to stress beyond which faulting occurs and by the presence of drilling-induced tensile fractures in some wells. The maximum horizontal stress magnitude can only be loosely constrained regionally using frictional limits, due to the variability of both the minimum horizontal stress and vertical stress estimates. However, the maximum horizontal stress and thus the full stress tensor can be better constrained at individual well locations, as demonstrated in Bulyeroo-1 and Dullingari North-8, where the necessary data (i.e. image logs, minifrac tests and density logs) are available. The stress magnitudes determined indicate a predominantly strike-slip fault stress regime ( SHmax > Sv > Shmin) at a depth of between 1 and 3 km in the Cooper-Eromanga Basins. However, some areas of the basin are transitional between strike-slip and reverse fault stress regimes ( SHmax > Sv ≈ Shmin). Large differential stresses in the Cooper-Eromanga Basins indicate a high upper crustal strength for the region, consistent with other intraplate regions. We propose that the in

  6. Application of Landsat imagery to problems of petroleum exploration in Qaidam Basin, China.

    USGS Publications Warehouse

    Bailey, G.B.; Anderson, P.D.

    1982-01-01

    Tertiary and Quaternary nonmarine, petroleum-bearing sedimentary rocks have been extensively deformed by compressive forces. These forces created many folds which are current targets of Chinese exploration programs. Image-derived interpretations of folds, strike-slip faults, thrust faults, normal or reverse faults, and fractures compared very favorably, in terms of locations and numbers mapped, with Chinese data compiled from years of extensive field mapping. Many potential hydrocarbon trapping structures were precisely located. Orientations of major structural trends defined from Landsat imagery correlate well with those predicted for the area based on global tectonic theory. These correlations suggest that similar orientations exist in the eastern half of the basin where folded rocks are mostly obscured by unconsolidated surface sediments and where limited exploration has occurred.--Modified journal abstract.

  7. Applied geointegration to hydrocarbon exploration in the San Pedro-Machango Area, Maracaibo Basin, Venezuela

    SciTech Connect

    Fonseca, A.; Navarro, A.; Osorio, R.; Corvo, F.; Arismendi, J.

    1996-08-01

    Hydrocarbon exploration has nowadays a diversity of technological resources to capture, merge and interpret information from diverse sources. To accomplish this, the integration of geodata for modeling was done through the use of new technologies like Remote Sensing and Geographical Systems of Information and applied to the San Pedro-Machango area, located in the Serrania de Trujillo, west of Costa Bolivar (onshore), eastern Maracaibo Basin, Venezuela. The main purpose of this work was to optimize the design of an exploration program in harmony with environmental conservation procedures. Starting with satellital and radar images that incorporated geophysical, geological and environmental information, they then were analyzed and merged to improve the lithological, structural and tectonic interpretation, generating an integrated model that allowed better project design. The use of a system that combines information of geographical, geodetical, geophysical and geological origins with satellital and radar images produced up to date cartography and refined results of image interpretation.

  8. Videotutoring at Appalachian State University.

    ERIC Educational Resources Information Center

    Buchanan, Harriette C.

    Initiated in early 1986, the Videotutoring Program at Appalachian State University, Boone (North Carolina), has proved to be a valuable tool for instructors in certain high risk courses (such as biology, history, and mathematics) for providing supplementary tutorial assistance for their students. The program was developed and is coordinated by the…

  9. Appalachian Women. An Annotated Bibliography.

    ERIC Educational Resources Information Center

    Hamm, Mary Margo

    This bibliography compiles annotations of 178 books, journal articles, ERIC documents, and dissertations on Appalachian women and their social, cultural, and economic environment. Entries were published 1966-93 and are listed in the following categories: (1) authors and literary criticism; (2) bibliographies and resource guides; (3) economics,…

  10. Southern Appalachian Regional Seismic Network

    SciTech Connect

    Chiu, S.C.C.; Johnston, A.C.; Chiu, J.M.

    1994-08-01

    The seismic activity in the southern Appalachian area was monitored by the Southern Appalachian Regional Seismic Network (SARSN) since late 1979 by the Center for Earthquake Research and Information (CERI) at Memphis State University. This network provides good spatial coverage for earthquake locations especially in east Tennessee. The level of activity concentrates more heavily in the Valley and Ridge province of eastern Tennessee, as opposed to the Blue Ridge or Inner Piedmont. The large majority of these events lie between New York - Alabama lineament and the Clingman/Ocoee lineament, magnetic anomalies produced by deep-seated basement structures. Therefore SARSN, even with its wide station spacing, has been able to define the essential first-order seismological characteristics of the Southern Appalachian seismic zone. The focal depths of the southeastern U.S. earthquakes concentrate between 8 and 16 km, occurring principally beneath the Appalachian overthrust. In cross-sectional views, the average seismicity is shallower to the east beneath the Blue Ridge and Piedmont provinces and deeper to the west beneath the Valley and Ridge and the North American craton. Results of recent focal mechanism studies by using the CERI digital earthquake catalog between October, 1986 and December, 1991, indicate that the basement of the Valley and Ridge province is under a horizontal, NE-SW compressive stress. Right-lateral strike-slip faulting on nearly north-south fault planes is preferred because it agrees with the trend of the regional magnetic anomaly pattern.

  11. Groundwater flow in an intermountain basin: Hydrological, geophysical, and geological exploration of South Park, Colorado

    NASA Astrophysics Data System (ADS)

    Ball, Lyndsay Brooke

    Groundwater in the intermountain basins of the American West is increasingly of interest with respect to water supply, ecosystem integrity, and contaminant and heat transport processes. These basins are defined by their heterogeneity through large topographic relief, substantial climatic variability, and permeability distributions made complex through variations in lithology and deformation over the orogenic history of these regions, leading to folded and faulted aquifers. This dissertation focuses on the influence of these heterogeneities on the groundwater flow system of the South Park basin in central Colorado, USA. The influence of faults on shallow groundwater flow was examined at two locations along the mapped trace of the Elkhorn fault, a Laramide reverse fault that juxtaposes crystalline and sedimentary rocks in eastern South Park. At the first location, electromagnetic, resistivity, self-potential, and hydraulic data were collected at an existing well field straddling the fault trace. Integrated analysis suggested the fault behaves as combined conduit barrier to groundwater in flow the upper 60 m. A second location along the mapped trace was selected through additional geophysical exploration. New boreholes were drilled to make direct geologic, hydrologic, and geophysical observations of the fault zone. However, these boreholes did not intersect the Elkhorn fault despite passing through rocks with similar electrical resistivity signatures to the first study location. Analyses of drill core and geophysical data indicate that the mineralogical composition of the crystalline rocks strongly influences their resistivity values, and the resistivity contrasts associated with the rock juxtaposition created by the Elkhorn fault is not unique. A steady-state, three-dimensional groundwater flow model of the South Park basin was developed to explore the influence of complex topography, recharge, and permeability structure on regional groundwater flow. Geologic

  12. The challenges of exploring near the fringes of space: A case history of seismically exploring the Altiplano Basin of Bolivia

    SciTech Connect

    Prideaux, B.R.; Bayne, J.W.

    1994-12-31

    Obtaining the quality seismic data necessary to answer key exploration questions in the Altiplano Basin of Bolivia necessitated the use of turbo-charged vibrators, ground force control electronics, and state of the art processing techniques. Overcoming the structural complexity of the region, including steep surface dips (averaging 45{degree}--50{degree}), even steeper subsurface dips adjacent to areas of near-flat dip, as well as substantial surface variations, required optimal recording and processing parameters. A long far offset (3056.75 m) and a close trace spacing (12.5 m) was needed to acquire the most reliable data. Seven second records were also recorded to insure that information was acquired at depth. Several other factors helped account for an acquisition success for the project. A field computer system was used to quickly process brute and enhanced brute stacks, which provided greater quality control and allowed for in-field adjustments to optimize the acquisition parameters. Additionally, the processing of the data was able to minimize numerous problems. There was a high variance in the recorded data quality, mainly due to surface and near-surface conditions (statics), as well as a fairly high degree of background noise throughout. These noise problems eventually determined the processing sequence that was used. Some processes that were initially proposed deteriorated instead of enhanced the interpretability of the seismic data.

  13. Strontium isotope quantification of siderite, brine and acid mine drainage contributions to abandoned gas well discharges in the Appalachian Plateau

    SciTech Connect

    Chapman, Elizabeth C.; Capo, Rosemary C.; Stewart, Brian W.; Hedin, Robert S.; Weaver, Theodore J.; Edenborn, Harry M.

    2013-04-01

    Unplugged abandoned oil and gas wells in the Appalachian region can serve as conduits for the movement of waters impacted by fossil fuel extraction. Strontium isotope and geochemical analysis indicate that artesian discharges of water with high total dissolved solids (TDS) from a series of gas wells in western Pennsylvania result from the infiltration of acidic, low Fe (Fe < 10 mg/L) coal mine drainage (AMD) into shallow, siderite (iron carbonate)-cemented sandstone aquifers. The acidity from the AMD promotes dissolution of the carbonate, and metal- and sulfate-contaminated waters rise to the surface through compromised abandoned gas well casings. Strontium isotope mixing models suggest that neither upward migration of oil and gas brines from Devonian reservoirs associated with the wells nor dissolution of abundant nodular siderite present in the mine spoil through which recharge water percolates contribute significantly to the artesian gas well discharges. Natural Sr isotope composition can be a sensitive tool in the characterization of complex groundwater interactions and can be used to distinguish between inputs from deep and shallow contamination sources, as well as between groundwater and mineralogically similar but stratigraphically distinct rock units. This is of particular relevance to regions such as the Appalachian Basin, where a legacy of coal, oil and gas exploration is coupled with ongoing and future natural gas drilling into deep reservoirs.

  14. Alteration mineralogy and geochemistry as an exploration tool for detecting basement heat sources in sedimentary basins

    NASA Astrophysics Data System (ADS)

    Uysal, Tonguc; Gasparon, Massimo; van Zyl, Jacobus; Wyborn, Doone

    2010-05-01

    The Cooper Basin located in South Australia and Queensland hosts some of the hottest granites in the world at economic drilling depths (240°C at 3.5 km). Investigating the mechanism of heat-producing element enrichment in the Cooper Basin granite is crucial for understanding hot-dry rock geothermal systems and developing exploration strategies. Trace element (by ICP-MS) and stable isotope geochemistry of whole rock granite samples and hydrothermal phyllosilicate alteration minerals separated from the granite and overlying sandstones and mudstones of the Cooper Basin were examined in detail. Granite core samples from relatively shallow depths in Moomba 1 and Big Lake 1 are strongly altered with pervasive sericite (illite) and quartz precipitation, probably associated with intense micro-fracturing and veining. The intensity of hydrothermal alteration is less in deeper samples from Mcleod 1, Jolokia and Habanero 1. Highly altered granites from former holes are substantially enriched in lithophile elements, particularly in Cs, Rb, Be, Th, U and rare earth elements (REE) relative to the upper continental crust (UCC). U and Th contents with concentrations of up to 30 and 144 ppm, respectively, are 10 and 13 times higher than those of the UCC. Comparison of the trace element composition of the same samples dissolved by open beaker acid digestion and high-pressure acid bomb digestion (to dissolve zircon) shows that zircon is not the main repository of U and Th in the Cooper Basin granite. Instead, we propose that the enrichment of heat-producing elements was promoted by a regional hydrothermal event leading to the precipitation of U and Th- bearing minerals such as illite, K-feldspar and thorite. Crystallinity index (illite crystallinity) of the sericite indicates hydrothermal temperatures ranging from 250°C (in Moomba 1 and Big Lake 1) to 350°C (in McLeod 1 and Jolokia 1). In the overlying sedimentary rocks, crystallinity of authigenic illites translates to lower

  15. The Nordkapp Basin, Norway: Development of salt and sediment interplays for hydrocarbon exploration

    SciTech Connect

    Lerche, I.; Toerudbakken, B.O.

    1996-12-31

    Investigation of a particular salt diapir in the Nordkapp Basin, Barents Sea has revealed the following sequence of events: (1) salt started to rise when approximately 1.5 {+-} 0.3 km of sedimentary cover was present (Carboniferous/Permian time); (2) salt reached the sediment surface when about 3.5 {+-} 0.7 km of sediment had been deposited (Triassic time); (3) the mushroom cap on the salt stock top developed over a period of about 75--100 Ma (i.e. during the time when about another km of sediment had been deposited) (Triassic through Base Cretaceous time); (4) the mushroom cap started to dip down significantly ({approximately}1 km) into the sediments around Cretaceous to Tertiary erosion time; (5) oil generation started in the deep sediments of the Carboniferous around the time that salt reached the surface (Triassic time) and continues to the present day at sedimentary depths between about 4 to 7 km (currently Triassic and deeper sediments); (6)gas generation started around mushroom cap development time and continues to the present day at sedimentary depths greater than about 6--7 km (Permian/Carboniferous); (7) the salt stock is currently 3--4 km wide, considerably less than the mushroom cap which is 9 km wide and 1 km thick. The relative timing of mushroom cap development, bed upturning, and hydrocarbon generation makes the salt diapir an attractive exploration target, with suggested reservoir trapping under the downturned mushroom cap on the deep basin side of the salt. In addition, rough estimates of rim syncline fill suggest the basin had an original salt thickness of 2.4--3.3 km, depending upon the amount of salt removed at the Tertiary erosion event.

  16. Geothermal GIS coverage of the Great Basin, USA: Defining regional controls and favorable exploration terrains

    USGS Publications Warehouse

    Coolbaugh, M.F.; Sawatzky, D.L.; Oppliger, G.L.; Minor, T.B.; Raines, G.L.; Shevenell, L.; Blewitt, G.; Louie, J.N.

    2003-01-01

    A geographic information system (GIS) of geothermal resources, built last year for the state of Nevada, is being expanded to cover the Great Basin, USA. Data from that GIS is being made available to industry, other researchers, and the public via a web site at the Great Basin Center for Geothermal Energy, Reno, Nevada. That web site features a search engine, supports ArcExplorer?? for on-line map construction, and provides downloadable data layers in several formats. Though data collection continues, preliminary analysis has begun. Contour maps of geothermal temperatures, constructed using geothermometer temperatures calculated from a Great Basin geochemical database compiled by the Geo-Heat Center, reveal distinctive trends and patterns. As expected, magmatic-type and extensional-type geothermal systems have profoundly different associations, with magmatic-type systems following major tectonic boundaries, and extensional-type systems associating with regionally high heat flow, thin crust, active faulting, and high extensional strain rates. As described by earlier researchers, including Rowen and Wetlaufer (1981) and Koenig and McNitt (1983), high-temperature (> 100??C) geothermal systems appear to follow regional northeast trends, most conspicuously including the Humboldt structural zone in Nevada, the "Black Rock-Alvord Desert" trend in Oregon and Nevada, and the "Newcastle-Roosevelt" trend in Utah and Nevada. Weights-of-evidence analyses confirm a preference of high-temperature geothermal systems for young northeast-trending faults, but the distribution of geothermal systems correlates even better with high rates of crustal extension, as measured from global positioning system (GPS) stations in Nevada. A predictive map of geothermal potential based only on areas of high extensional strain rates and high heat flux does an excellent job of regionally predicting the location of most known geothermal systems in Nevada, and may prove useful in identifying blind

  17. Relative importance of physical and economic factors in Appalachian coalbed gas assessment

    USGS Publications Warehouse

    Attanasi, E.D.

    1998-01-01

    In the 1995 National Assessment of Oil and Gas Resources prepared by the U.S. Geological Survey, only 20% of the assessed technically recoverable Appalachian Province coalbed gas resources were economic. Physical and economic variables are examined to explain the disparity between economic and technically recoverable coalbed gas. The Anticline and Syncline plays of the Northern Appalachian Basin, which account for 77% of the assessed technically recoverable coalbed gas, are not economic. Analysis shows marginal reductions in costs or rate of return will not turn these plays into commercial successes. Physical parameters that determine ultimate well recoverability and the rate of gas recovery are primary reasons the Northern Appalachian Basin plays are non-commercial. If the application of new well stimulation technology could offset slow gas desorption rates, Appalachian Province economic gas could increase to more then 70% of the technically recoverable gas. Similarly, if operators are able to develop strategies to selectively drill plays by avoiding dry holes and non-commercial occurrences, the economic fraction of technically recoverable gas could increase to over half.In the 1995 National Assessment of Oil and Gas Resources prepared by the U.S. Geological Survey, only 20% of the assessed technically recoverable Appalachian Province coalbed gas resources were economic. Physical and economic variables are examined to explain the disparity between economic and technically recoverable coalbed gas. The Anticline and Syncline plays of the Northern Appalachian Basin, which account for 77% of the assessed technically recoverable coalbed gas, are not economic. Analysis shows marginal reductions in costs or rate of return will not turn these plays into commercial successes. Physical parameters that determine ultimate well recoverability and the rate of gas recovery are primary reasons the Northern Appalachian Basin plays are non-commercial. If the application of new well

  18. Exploring Unconventional Hydrocarbons in the Makó Trough, Pannonian basin, Hungary: Results and Challenges

    NASA Astrophysics Data System (ADS)

    Horvath, Anita; Bada, Gabor; Szafian, Peter; Sztano, Orsolya; Law, Ben; Wallis, Rod

    2010-05-01

    The latest phase exploration in the Makó Trough, which commenced a few years ago, has focused on the utilization of unconventional hydrocarbons. Accumulations are regarded as "unconventional" when they cannot be produced economically except by means of some sort of stimulation, usually hydraulic fracturing. The model we have developed for the evaluation of the hydrocarbon potential indicates a significant gas accumulation in the area of the Makó Trough. The tally of the distinctive attributes of the hydrocarbon system and the combined analysis of the available geological data led to the conclusion that the Makó Trough represents an area of active basin-centered gas accumulation (BCGA), with very significant perspective reserves. In a BCGA, hydrocarbons do not accumulate conventionally, in structural or stratigraphic traps, but rather in cells. Due to the geological setting of the Makó Trough, the hydrocarbon cell here forms a relatively continuous zone marked by considerable internal lithological and petrophysical variability. The most prolific parts, called sweet spots, possess a reservoir potential higher than the average. The identification of these sweet spots constitutes one of the most important, and quite possibly the most challenging task of the entire exploration project. The hemipelagic Endrőd Formation, which acts as the source rock, contains organic-rich marls in a depth delimited by the 170-230 °C isotherms. These marls constitute the still active hydrocarbon "kitchen" of the BCGA in the Makó Trough. The top and bottom boundaries of the cell essentially coincide with the turbidites of the Szolnok Formation and the top of the pre-Neogene basement, respectively. In light of the fact that pressure, temperature, and maturity tests have produced rather similar results in a number of wells in the area, we have reason to believe that the extension of the Makó Trough's BCGA is of regional dimensions (>1000 km2). The thickness and lateral extension of

  19. Cancer Mortality in Rural Appalachian Kentucky. Appalachian Data Bank Report #6.

    ERIC Educational Resources Information Center

    Tucker, Thomas C.; And Others

    This report compares cancer mortality rates in rural Appalachian Kentucky with rates for rural non-Appalachian Kentucky and the U.S. white population. Rural Appalachian Kentucky differs from the rest of rural Kentucky in having a younger, poorer, less educated population with greater employment in mining as opposed to agriculture, and with less…

  20. Exploration of the lower permeability reservoir in Sanzhao area of Songliao Basin

    SciTech Connect

    Ding Guiming; Wang Yuxin )

    1996-01-01

    Sanzhao area is an independent petroleum generation-migration-accumulation unit that concentrates in the Sanzhao sag, a large sag in the central depression of Songliao basin. The oil generated from the Lower Cretaceous Qingshankou Formation migrated into Fuyu and Yangdachengzi reservoirs in Members 3 and 4 of the Quantou Formation, with the overpressure of the source bed driving fluids through dense fault pathways. Fuyu and Yangdachengzi reserviors are formed by areally-extensive, fluviodeltaic thin interbedded sandstones. Most of the oil pools in Sanzhao area are in low-permeability lithologies. In order to prospect for these lower permeability reservoirs, first we set evaluation and oil/gas reservoir evaluation. On the basis of the composite study of petroleum geology, the low-permeability feature of Fuyu and Yangdachengzi reservoirs has been further understood. Secondly, we have developed a series of exploration methods and techniques, including high-resolution seismic exploration, oil testing and fracturing, and techniques for protecting oil reservoirs. Due to breakthrough in understanding of petroleum geology and the development of composite exploration techniques, the low-permeability reservoirs of Sanzhao area have liberated abundant reservers. A large, low-permeability oil province with reserves of more than 10x10[sup 8] has been proven.

  1. Streamflow Generation on Small Forested Central Appalachian Watersheds

    NASA Astrophysics Data System (ADS)

    Hicks, N. S.; Smith, J. A.; Miller, A. J.

    2005-12-01

    This study examines streamflow generation and extreme flood response for high-gradient, forested central Appalachian watersheds. Streamflow and rainfall observations are combined with observations from a network of 415 crest-stage piezometers on two headwater watersheds (0.30 and 0.14 km2) at the Fernow Experimental Forest near Parsons, WV, to examine the storm event response of forested Appalachian watersheds. Piezometer nests (piezometer depths of 25, 50, and 100 cm) were used to identify perched water tables and to distinguish between different runoff production mechanisms. A conceptual model of runoff processes in these watersheds includes the formation of localized perched water tables due to decreased macropores and increased flaggy stones with increasing depth in the soil column. This model is an extension of the variable source area. During small and moderate sized events, subsurface saturation observed in the swales supports the idea of expanding variable source areas; during extreme events, the development of perched water tables in the shallow subsurface and rapid progression of saturated conditions to the surface becomes increasingly important. Contributions from perched water tables are spatially and temporally variable and dependent upon preferential flow pathways and decreases in effective vertical hydraulic conductivity. This extension of the variable source area model of streamflow production is necessary to explain anomalously fast response times and large runoff ratios observed during extreme events on forested central Appalachian watersheds. Subsurface saturation over large portions of a watershed is infrequent in forested central Appalachian basins, but may play a central role in extreme flood response.

  2. A water system model for exploring electric energy alternatives in southeastern US basins

    NASA Astrophysics Data System (ADS)

    Flores-López, F.; Yates, D.

    2013-09-01

    Electric power generation often involves the use of water for power plant cooling and steam generation, which typically involves the release of cooling water to nearby rivers and lakes. The resulting thermal pollution may negatively impact the ecosystems of these water bodies. Water resource systems models enable the examination of the implications of alternative electric generation on regional water resources. This letter documents the development, calibration, and validation of a climate-driven water resource systems model of the Apalachicola-Chattahoochee-Flint, the Alabama-Coosa-Tallapoosa, and the Tombigbee River basins in the states of Georgia, Alabama, and Florida, in the southeastern US. The model represents different water users, including power plants, agricultural water users, and municipal users. The model takes into account local population, per-capita use estimates, and changes in population growth. The water resources planning model was calibrated and validated against the observed, managed flows through the river systems of the three basins. Flow calibration was performed on land cover, water capacity, and hydraulic conductivity of soil horizons; river water temperature calibration was performed on channel width and slope properties. Goodness-of-fit statistics indicate that under 1980-2010 levels of water use, the model robustly represents major features of monthly average streamflow and water temperatures. The application of this integrated electricity generation-water resources planning model can be used to explore alternative electric generation and water implications. The implementation of this model is explored in the companion paper of this focus issue (Yates et al 2013 Environ. Res. Lett. 8 035042).

  3. An evaluation of the suitability of ERTS data for the purposes of petroleum exploration. [Anadarko Basin of Texas and Oklahoma

    NASA Technical Reports Server (NTRS)

    Collins, R. J.; Mccown, F. P.; Stonis, L. P.; Petzel, G.; Everett, J. R.

    1974-01-01

    This experiment was designed to determine the types and amounts of information valuable to petroleum exploration extractable from ERTS data and the cost of obtaining the information using traditional or conventional means. It was desired that an evaluation of this new petroleum exploration tool be made in a geologically well known area in order to assess its usefulness in an unknown area. The Anadarko Basin lies in western Oklahoma and the panhandle of Texas. It was chosen as a test site because there is a great deal of published information available on the surface and subsurface geology of the area, and there are many known structures that act as traps for hydrocarbons. This basin is similar to several other large epicontinental sedimentary basins. It was found that ERTS imagery is an excellent tool for reconnaissance exploration of large sedimentary basins or new exploration provinces. For the first time, small and medium size oil companies can rapidly and effectively analyze exploration provinces as a whole.

  4. Play-fairway analysis for geothermal exploration: Examples from the Great Basin, western USA

    SciTech Connect

    Siler, Drew L; Faulds, James E

    2013-10-27

    Elevated permeability within fault systems provides pathways for circulation of geothermal fluids. Future geothermal development depends on precise and accurate location of such fluid flow pathways in order to both accurately assess geothermal resource potential and increase drilling success rates. The collocation of geologic characteristics that promote permeability in a given geothermal system define the geothermal ‘fairway’, the location(s) where upflow zones are probable and where exploration efforts including drilling should be focused. We define the geothermal fairway as the collocation of 1) fault zones that are ideally oriented for slip or dilation under ambient stress conditions, 2) areas with a high spatial density of fault intersections, and 3) lithologies capable of supporting dense interconnected fracture networks. Areas in which these characteristics are concomitant with both elevated temperature and fluids are probable upflow zones where economic-scale, sustainable temperatures and flow rates are most likely to occur. Employing a variety of surface and subsurface data sets, we test this ‘play-fairway’ exploration methodology on two Great Basin geothermal systems, the actively producing Brady’s geothermal system and a ‘greenfield’ geothermal prospect at Astor Pass, NV. These analyses, based on 3D structural and stratigraphic framework models, reveal subsurface characteristics about each system, well beyond the scope of standard exploration methods. At Brady’s, the geothermal fairways we define correlate well with successful production wells and pinpoint several drilling targets for maintaining or expanding production in the field. In addition, hot-dry wells within the Brady’s geothermal field lie outside our defined geothermal fairways. At Astor Pass, our play-fairway analysis provides for a data-based conceptual model of fluid flow within the geothermal system and indicates several targets for exploration drilling.

  5. Appalachian clean coal technology consortium

    SciTech Connect

    Kutz, K.; Yoon, Roe-Hoan

    1995-11-01

    The Appalachian Clean Coal Technology Consortium (ACCTC) has been established to help U.S. coal producers, particularly those in the Appalachian region, increase the production of lower-sulfur coal. The cooperative research conducted as part of the consortium activities will help utilities meet the emissions standards established by the 1990 Clean Air Act Amendments, enhance the competitiveness of U.S. coals in the world market, create jobs in economically-depressed coal producing regions, and reduce U.S. dependence on foreign energy supplies. The research activities will be conducted in cooperation with coal companies, equipment manufacturers, and A&E firms working in the Appalachian coal fields. This approach is consistent with President Clinton`s initiative in establishing Regional Technology Alliances to meet regional needs through technology development in cooperation with industry. The consortium activities are complementary to the High-Efficiency Preparation program of the Pittsburgh Energy Technology Center, but are broader in scope as they are inclusive of technology developments for both near-term and long-term applications, technology transfer, and training a highly-skilled work force.

  6. Comparing the trends of elevated blood pressure in appalachian and non-Appalachian regions.

    PubMed

    Shandera-Ochsner, Anne L; Han, Dong Y; Rose, Danny; Aroor, Sushanth R; Schmitt, Frederick; Bellamy, Lisa M; Dobbs, Michael R

    2014-10-01

    As an established risk factor for cardiovascular disease and stroke, hypertension risks are often thought to be more prevalent in Appalachian mountain ranges when compared with other neighboring counterpart regions. This study evaluated blood pressure (BP) readings among 2358 Kentucky residents attending community stroke risk screening events held in 15 counties, including nine Appalachian counties (n=1134) and six non-Appalachian counties (n=1224). With high BP being operationally defined as ≥140/90 mm Hg, 41.5% of Appalachian county residents had elevated BP compared with 42.6% among those from non-Appalachian counties. Although the counties with the highest rates of elevated BP did tend to reside in the Appalachian region, there was no significant difference between rates of elevated BP in Appalachia vs non-Appalachian counties. This dataset is proposed as a pilot project to encourage further pursuit of a larger controlled project.

  7. Delineation of Piceance Basin basement structures using multiple source data: Implications for fractured reservoir exploration

    SciTech Connect

    Hoak, T.E.; Klawitter, A.L.

    1995-10-01

    Fractured production trends in Piceance Basin Cretaceous-age Mesaverde Group gas reservoirs are controlled by subsurface structures. Because many of the subsurface structures are controlled by basement fault trends, a new interpretation of basement structure was performed using an integrated interpretation of Landsat Thematic Mapper (TM), side-looking airborne radar (SLAR), high altitude, false color aerial photography, gas and water production data, high-resolution aeromagnetic data, subsurface geologic information, and surficial fracture maps. This new interpretation demonstrates the importance of basement structures on the nucleation and development of overlying structures and associated natural fractures in the hydrocarbon-bearing section. Grand Valley, Parachute, Rulison, Plateau, Shire Gulch, White River Dome, Divide Creek and Wolf Creek fields all produce gas from fractured tight gas sand and coal reservoirs within the Mesaverde Group. Tectonic fracturing involving basement structures is responsible for development of permeability allowing economic production from the reservoirs. In this context, the significance of detecting natural fractures using the intergrated fracture detection technique is critical to developing tight gas resources. Integration of data from widely-available, relatively inexpensive sources such as high-resolution aeromagnetics, remote sensing imagery analysis and regional geologic syntheses provide diagnostic data sets to incorporate into an overall methodology for targeting fractured reservoirs. The ultimate application of this methodology is the development and calibration of a potent exploration tool to predict subsurface fractured reservoirs, and target areas for exploration drilling, and infill and step-out development programs.

  8. North America as an exotic terrane'' and the origin of the Appalachian--Andean Mountain system

    SciTech Connect

    Dalziel, I.W.D; Gahagan, L.M. . Inst. for Geophysics); Dalla Salda, L.H. . Centro de Investigaciones Geologicas)

    1992-01-01

    North America was sutured to Gondwana in the terminal Alleghanian event of Appalachian orogenesis, thus completing the late Paleozoic assembly of Pangea. The suggestion that the Pacific margins of East Antarctica-Australia and Laurentia may have been juxtaposed during the Neoproterozoic prompts reevaluation of the widely held assumptions that the ancestral Appalachian margin rifted from northwestern Africa during the earliest Paleozoic opening of Iapetus, and remained juxtaposed to that margin, even though widely separated from it at times, until the assembly of Pangea. The lower Paleozoic carbonate platform of northwestern Argentina has been known for a long time to contain Olenellid trilobites of the Pacific or Columbian realm. Although normally regarded as some kind of far-travelled terrane that originated along the Appalachian margin of Laurentia, it has recently been interpreted as a fragment detached from the Ouachita embayment of Laurentia following Taconic-Famatinian collision with Gondwana during the Ordovician. The Oaxaca terrane of Mexico, on the other hand, contains a Tremadocian trilobite fauna of Argentine-Bolivian affinities, and appears to have been detached from Gondwana following the same collision. The Wilson cycle'' of Iapetus ocean basin opening and closing along the Appalachian and Andean orogens may have involved more than one such continental collision during clockwise drift of Laurentia around South America following late Neoproterozoic to earliest Cambrian separation. Together with the collisions of baltic and smaller terranes with Laurentia, this could explain the protracted Paleozoic orogenic history of both the Appalachian and proto-Andean orogens.

  9. Prospects for Learning in River Management: Exploring the Initial Implementation of the Water Framework Directive in a Swedish River Basin

    ERIC Educational Resources Information Center

    Lundmark, Carina; Jonsson, Gunnar

    2014-01-01

    This case study explores the initial implementation of the EU Water Framework Directive (WFD) in the Lule River basin, Sweden, examining how and to what extent administrative procedures enable learning through dialogue and stakeholder collaboration. Theorising on adaptive co-management and social learning is used to structure what is to be learnt,…

  10. Assessing Basic Skill Performance in Appalachian Kentucky.

    ERIC Educational Resources Information Center

    DeYoung, Alan J.; Vaught, Charles

    Basic skill performance levels of third-, fifth-, seventh-, and tenth-grade students attending schools in the Appalachian School Districts of Kentucky are reported and discussed. School district scores on the reading, language and mathematics subtests of the Comprehensive Test of Basic Skills clearly show that children in most Appalachian school…

  11. The Appalachian Band in the Moral Spectrum.

    ERIC Educational Resources Information Center

    Snyder, Bob

    1995-01-01

    Reviews "Appalachian Values," by author Loyal Jones and photographer Warren Brunner, which depicts the culture and values characteristic of Appalachian people. Although the book successfully illustrates the moral core of Appalachia, values are presented in a noncontroversial form, rather than as a part of individual or social conflict. (LP)

  12. Appalachian Regional Commission. Annual Report 1969.

    ERIC Educational Resources Information Center

    Appalachian Regional Commission, Washington, DC.

    After 4 years of operation, the Appalachian Regional Commission (ARC) presents this 1969 annual report and evaluation of its activities as required by the Appalachian Regional Development Act of 1965. A brief overview is given of the history of the program, the Federal-state relationship, and strategies for regional development. Appalachia is then…

  13. Appalachian English Stereotypes: Language Attitudes in Kentucky.

    ERIC Educational Resources Information Center

    Luhman, Reid

    1990-01-01

    Employs the matched guise technique to compare attitudes in Kentucky about Appalachian English and Standard American English held by speakers of both language varieties. The study suggests that speakers of Appalachian English partially accept low status evaluation of their dialect, but reject other negative stereotypes about their community…

  14. An improved model for the evolution of the Pannonian basin and some of its consequences for hydrocarbon exploration

    SciTech Connect

    Horvath, F. ); Pogascsas, G.; Szabo, A. ); Cloethingh, S.; Reemst, P. )

    1993-09-01

    New data from industrial and academic reflection seismic profiling allow construction of long geological sections across the Pannonian basin depicting the geometry of the sedimentary troughs and the underlying crust. In addition, recent results of sequence stratigraphic analyses, combined with a couple of magnetostratigraphically dated borehole sections, have led to a precise knowledge of the regional chronostratigraphic conditions and facies changes in the basin fill. The inferred subsidence history reveals interesting anomalies, particularly during the late stage period. The central part (Great Hungarian Plain) has undergone accelerated subsidence, while its western flank (Transdanubia and Styrian basin) as well as the eastern flank (Apuseni Mountains and Transylvanian basin) experienced uplift. Modeling of the subsidence history using two-dimensional algorithms and realistic rheological profiles for the lithosphere explains these observations in terms of a remarkable increase of intraplate stress, as recent as 4 to 2 Ma. Our new model can have an important bearing on hydrocarbon exploration in the Pannonian basin because it provides a better temperature history and allows more accurate prediction of maturity conditions, calls attention to the significance of late-stage fault reactivation and folding in producing traps, and suggests that stress increase and uplift of geopressured basin and/or basement rocks could have induce massive fracturing and, thus, created high secondary permeability conditions and a revival of fluid-flow systems.

  15. Unraveling the hydrocarbon charge potential of the Nordkapp Basin, Barents Sea: An integrated approach to reduce exploration risk in complex salt basins

    NASA Astrophysics Data System (ADS)

    Schenk, Oliver; Shtukert, Olga; Bishop, Andrew; Kornpihl, Kristijan; Milne, Graham

    2014-05-01

    The Nordkapp Basin, Barents Sea, is an intra-continental syn-rift basin containing many complex salt structures. The salt is late-Carboniferous to Early Permian in age, with regional extension in the Triassic initiating the salt movement resulting in formation of sub- and mini-basins with significant subsidence (especially in the northeastern part of the basin). Subsequent tectonic phases allowed growth and distortion of salt diapirs that were later affected by uplift and erosion during Tertiary resulting in the formation of salt-related traps in Triassic and Lower Jurassic strata. During Plio-Pleistocene, glacial erosion removed additional Mesozoic and Cenozoic strata. This basin is regarded as a frontier salt province. A small hydrocarbon discovery (Pandora well) in the southwestern part of the basin points to the presence several functioning petroleum systems. The primary play type is related to salt traps below overhangs. Such structures are however, very difficult to image with conventional seismic techniques due to i) generation of multiples from sea floor and top of shallow salt bodies and ii) seismic shadow zones within the salt (possibly resulting from shale and carbonate stringers) which cause severe diffractions so that prospective areas adjacent to the salt remain elusive. Arctic exploration is expensive and the ability to focus on the highest potential targets is essential. A unique solution to this challenging subsurface Arctic environment was developed by integrating petroleum system modeling with full azimuth broadband seismic acquisition and processing. This integrated approach allows intelligent location of seismic surveys over structures which have the maximum chance of success of hydrocarbon charge. Petroleum system modeling was conducted for four seismic sections. Salt was reconstructed according to the diapiric evolution presented in Nilsen et al. (1995) and Koyi et al. (1995). Episodes of major erosion were assigned to Tertiary (tectonic) and

  16. Lower Cretaceous Avile Sandstone, Neuquen basin, Argentina - Exploration model for a lowstand clastic wedge in a back-arc basin

    SciTech Connect

    Ryer, T.A. )

    1991-03-01

    The Neuquen basin of western Argentina is a back-arc basin that was occupied by epeiric seas during much of Jurassic and Cretaceous time. The Avile Sandstone Member of the Agrio Formation records a pronounced but short-lived regression of the Agrio sea during middle Hauterivian (Early Cretaceous) time. Abrupt lowering of relative sea level resulted in emergence and erosion of the Agrio sea floor; shoreline and fluvial facies characteristic of the Centenario Formation shifted basinward. The Avile rests erosionally upon lower Agrio shale over a large area; well-sorted, porous sandstones within the member pinch out laterally against the base-Avile erosional surface. Avile deposition closed with an abrupt transgression of the shoreline to the approximate position it had occupied prior to the Avile regression. The transgressive deposits are carbonate rich, reflecting starvation of the basin as a consequence of sea-level rise. The Avile lowstand clastic wedge consists predominantly of sandstones deposited in fluvial to shallow-marine paleoenvironments; eolian sandstones probably constitute an important component in the eastern part of the area. The sandstones locally have excellent reservoir characteristics; they constitute the reservoirs in the Puesto Hernandez, Chihuido de la Sierra Negra, and Filo Morado fields. The pinch-out of the Avile lowstand clastic wedge has the potential to form stratigraphic traps in favorable structural positions. The depositional model indicates that there may be a viable stratigraphic play to be made along the Avile pinch-out in the deep, relatively undrilled, northwestern part of the Neuquen basin.

  17. Seismic exploration for oil and gas traps in Wind River Basin: a Laramide example

    SciTech Connect

    Ray, R.R.; Keefer, W.R.

    1985-05-01

    The Wind River Basin in central Wyoming is typical of the large sedimentary and structural basins that formed in the Rocky Mountain region during the Laramide deformation in latest Cretaceous and early Tertiary times. Northeast-southwest-oriented seismic profiles across the Wind River basin and flanking Owl Creek and Bighorn Mountains illustrate the structural configuration and correspondent stratigraphic development of a typical Laramide intermontane basin. Understanding the geometry of the basin margin and the timing of structural movement aids in prospecting for mountain-front subthrust structures, like Tepee Flats field, and stratigraphic traps, like Haybarn field, in fluvial and lacustrine basin-fill sequences. The Wind River basin is structurally asymmetric with the basin axis close to the Owl Creek Mountains and Casper Arch thrusts, which form the north and east basin boundaries. Major Laramide deformation began in latest Cretaceous time (beginning of Lance Formation deposition) with pronounced downwarping of the basin trough and broad doming of parts of the peripheral areas. The intensity of movement increased through the Paleocene and culminated in early Eocene time as high mountains were uplifted along thrust faults. Clastic debris, stripped from the surrounding rising mountain arches, was shed basinward, resulting in a pronounced wedge-shaped accumulation of fluvial and lacustrine sediments now representing the Lance, Fort Union, Indian Meadows, and Wind River Formations.

  18. Subsidence history of the Alabama promontory in response to Late Paleozoic Appalachian-Ouachita thrusting

    SciTech Connect

    Whitting, B.M.; Thomas, W.A. . Dept. of Geological Sciences)

    1994-03-01

    The Alabama promontory of North American continental crust was framed during late Precambrian-Cambrian rifting by the northeast-striking Blue Ridge rift and the northwest-striking alabama-Oklahoma transform fault. A passive margin persisted along the western side of the promontory from Cambrian to Mississippian time, but the eastern side was affected by the Taconic and Acadian orogenies. Prior to initiation of Ouachita and Appalachian (Alleghanian) thrusting, the outline of the rifted margin of continental crust on the Alabama promontory remained intact; and the late paleozoic thrust belt conformed to the shape of the promontory, defining northwest-striking Ouachita thrust faults along the southwest side of the promontory, north-striking Appalachian (Georgia-Tennessee) thrust faults on the east, and northeast-striking Appalachian (Alabama) thrust faults across the corner of the promontory. Subsidence profiles perpendicular to each of the strike domains of the thrust belt have been constructed by calculating total subsidence from decompacted thickness of the synorogenic sedimentary deposits. The profile perpendicular to the Ouachita thrust belt shows increasing subsidence rates through time and toward the thrust front, indicating the classic signature of an orogenic foreland basin. The profile perpendicular to the Georgia-Tennessee Appalachian thrust belt similarly shows increasing subsidence rates through time and toward the orogenic hinterland. These quantitative results support the conclusion that Black Warrior basin subsidence is tectonically rather than sedimentologically driven, and the timing of subsidence events reported here has implications for regional tectonic models.

  19. Flood response for the watersheds of the Fernow Experimental Forest in the central Appalachians

    NASA Astrophysics Data System (ADS)

    Bates, Naomi S.; Smith, James A.; Villarini, Gabriele

    2015-06-01

    We examine flood response of high-gradient, forested central Appalachian watersheds through analyses of rainfall, streamflow, and piezometer observations from the Fernow Experimental Forest near Parsons, West Virginia. Analyses focus on hydrologic processes that control the "upper tail" of flood distributions. The largest flood peaks in the Fernow are an order of magnitude smaller than record floods in the central Appalachian region (for basins of comparable drainage area). We examine flood distributions in the Fernow using extreme value distributions (Generalized Extreme Value and Generalized Pareto distributions) and compare them to other watersheds in the central Appalachians. To examine the role of antecedent soil moisture on flood response, we installed a network of 415 crest-stage piezometers on two headwater watersheds (0.30 and 0.14 km2) of the Fernow. Observations show pronounced heterogeneity of subsurface saturation even within the unchannelized swales of headwater watersheds. Shallow perched water tables over large portions of a watershed occur infrequently in forested central Appalachian basins, but may play an important role in extreme flood response. Fernow watersheds include "treated" and control watersheds with stream gaging records extending back to 1951. We examine nonstationarites in flood frequency in the Fernow and show that forest management practices have had relatively minor impacts on flood frequency.

  20. Exploration for shallow, compaction-induced gas accumulations, Fort Union Formation, Powder River Basin, Wyoming

    SciTech Connect

    Oldham, D.W.

    1996-06-01

    Commercial quantities of gas have been produced from shallow sandstone reservoirs of the Fort Union Formation (Paleocene) in the Powder River Basin of Wyoming. The two largest accumulations discovered to date, Oedekoven and Chan pools, were drilled on prospects which invoked differential compaction as a mechanism for gas entrapment and prospect delineation. Gas is believed to have accumulated in localized structural highs early in the burial history of lenticular sands. Structural relief is due to the compaction contrast between sand and stratigraphically-equivalent fine-grained sediments. A shallow Fort Union gas play was based on reports of shallow gas shows, the occurrence of thick coals which could have served as sources for bacterial gas, and the presence of lenticular sandstones which may have promoted the development of compaction structures early in the burial process, to which bacterial gas migrated. Five geologic elements related to compactional trap development were used to rank prospects. Drilling of the Oedekoven prospect, which possessed all prospect elements, led to the discovery of the Oedekoven Fort Union gas pool at a depth of 340 ft (104 m). The uncemented, very fine grained, well-sorted {open_quotes}Canyon sand{close_quotes} pay has extremely high intergranular porosity. Low drilling and completion costs associated with shallow, high-permeability reservoirs, an abundance of subsurface control with which to delineate prospects, and existing gas-gathering systems make Fort Union sandstones attractive primary targets in shallow exploration efforts as well as secondary objectives in deeper drilling programs.

  1. Applications of Geophysical and Geological Techniques to Identify Areas for Detailed Exploration in Black Mesa Basin, Arizona

    SciTech Connect

    George, S.; Reeves, T.K.; Sharma, Bijon; Szpakiewicz, M.

    1999-04-29

    A recent report submitted to the U.S. Department of Energy (DOE) (NIPER/BDM-0226) discussed in considerable detail, the geology, structure, tectonics, and history of oil production activities in the Black Mesa basin in Arizona. As part of the final phase of wrapping up research in the Black Mesa basin, the results of a few additional geophysical studies conducted on structure, stratigraphy, petrophysical analysis, and oil and gas occurrences in the basin are presented here. A second objective of this study is to determine the effectiveness of relatively inexpensive, noninvasive techniques like gravity or magnetic in obtaining information on structure and tectonics in sufficient detail for hydrocarbon exploration, particularly by using the higher resolution satellite data now becoming available to the industry.

  2. Re-exploration of cratonic basins using passive-margin sequence-stratigraphic concepts: examples from upper Paleozoic rocks, eastern margin, Midland basin

    SciTech Connect

    Brown, L.F. Jr.

    1989-03-01

    Use of 5000 well logs and extensive outcrop information with a 22,000-mi/sup 2/ test region on the eastern margin of the Midland basin permitted delineation of 16 probably third-order type 1 depositional sequences. Sandstone-isolith maps of siliciclastic highstand and lowstand systems tracts show that most structural traps produce from highstand fluvial-deltaic reservoirs, but most stratigraphic traps discovered to date occur within lowstand depositional systems, principally incised valley fills and basin-floor fans. Hydrocarbons are rarely trapped in retrogradational (transgressive) systems tracts. Maps of lowstand tracts refocus attention on reservoirs that can be predicted to exist basinward of preexisting shelf edges. A basinward shift of exploration emphasis from incised valley-fill reservoirs to other lowstand elements - such as basin-floor fans, canyon and leveed-channel fills, and lowstand progradational deltaic wedges - could lead to plays where lenticular reservoir sandstones and marine-condensed source and seal shales exhibit the optimum conditions for pinch-out traps.

  3. Conceptual models in exploration geochemistry-The Basin and Range Province of the Western United States and Northern Mexico

    USGS Publications Warehouse

    Lovering, T.G.; McCarthy, J.H.

    1978-01-01

    This summary of geochemical exploration in the Basin and Range Province is another in the series of reviews of geochemical-exploration applications covering a large region; this series began in 1975 with a summary for the Canadian Cordillera and Canadian Shield, and was followed in 1976 by a similar summary for Scandinavia (Norden). Rather than adhering strictly to the type of conceptual models applied in those papers, we have made use of generalized landscape geochemistry models related to the nature of concealment of ore deposits. This study is part of a continuing effort to examine and evaluate geochemical-exploration practices in different areas of the world. Twenty case histories of the application of geochemical exploration in both district and regional settings illustrate recent developments in techniques and approaches. Along with other published reports these case histories, exemplifying generalized models of concealed deposits, provide data used to evaluate geochemical-exploration programs and specific sample media. Because blind deposits are increasingly sought in the Basin and Range Province, the use of new sample media or anomaly-enhancement techniques is a necessity. Analysis of vapors or gases emanating from blind deposits is a promising new technique. Certain fractions of stream sediments show anomalies that are weak or not detected in conventional minus 80-mesh fractions. Multi-element analysis of mineralized bedrock may show zoning patterns that indicate depth or direction of ore. Examples of the application of these and other, more conventional methods are indicated in the case histories. The final section of this paper contains a brief evaluation of the applications of all types of sample media to geochemical exploration in the arid environment of the Basin and Range Province. ?? 1978.

  4. Petroleum geology of the Estancia basin, New Mexico: An exploration frontier

    SciTech Connect

    Broadhead, R.F. )

    1994-03-01

    The Estancia basin of central New Mexico is an asymmetric, north-south-trending structural depression that originated during the Pennsylvanian. The present-day basin covers 1600 mi[sup 2]. The basin is bounded on the east by the late Paleozoic Pedernal uplift, on the west by the Tertiary Manzano and Los Pinos Mountains, on the north by the Espanola basin, an do the south by Chupadera Mesa. The depth to the Precambrian ranges from 9000 ft in the eastern part of the basin to less than 1500 ft in the western part. Basin fill consists primarily of Pennsylvanian and Wolfcampian (Permian) clastics. The Pennsylvanian section contains significant shelf limestones in the western part of the basin. Forty-three exploratory wells have been drilled in the basin; only 17 have been drilled to Precambrian. Numerous shows of oil and gas have been reported. From the 1930s until the 1960s, CO[sub 2] was produced from lower Pennsylvanian sandstones in two small fields on the western flank of the basin. Dark-gray to black Pennsylvanian shales are probable source rocks. They are mature to marginally mature; TAI values range from less than 2.0 to 3.2. TOC is greater than 0.5% in many of these shales. Kerogen types are mixed amorphous, algal, herbaceous, and woody, indicating that gas, or both gas and oil, may have been generated. Pennsylvanian sandstones are good reservoirs. They are fine- to coarse-grained subarkosic arenites and quartz arenites. Porosity ranges from 10 to 20% in the more porous, coarser-grained sandstones.

  5. Exploration history and future potential of Paleogene and Mesozoic rocks in the substratum of the Pannonian basin, Hungary

    SciTech Connect

    Badocz, B. ); Szalay, A. ); Horvath, F. ); Koncz, I. )

    1991-08-01

    The substratum of Pannonian basin is made up of Paleogene and Mesozoic deposits and Paleozoic, mostly crystalline rocks. They have been studied for a long time at outcrops in and around the basin, and our knowledge has improved significantly due to recent drilling activity and seismic exploration. Geochemical data combined with facies interpretations suggest the following possible source rocks of pre-Neogene age: Lower Oligocene Tard clay, Lower Cretaceous pelagic marls, Upper Liassic (Toarcian) black shales, Lowest Jurassic coal-bearing strata (Gresten facies), and Upper Triassic bitumenous shales (Kossen beds). The most remarkable success in exploration in Mesozoic rocks has been the finding of the Nagylengyel oil field in 1951 (total production 21 million tons). Several smaller fields have been found more recently in fractured Mesozoic and Paleozoic reservoirs, although their source rock can be Miocene marls in nearby deep troughs. Simple mass-balance calculations of hydrocarbon gases in the Great Hungarian Plain, however, indicate that known gas reserves are much larger than the potential yield of all available Neogene source rocks. Analyses of gas content of individual pools and isotope geochemistry give evidence that massive gas flux from depth is still going on. Maturity studies also support the view that hydrocarbon generative potential of the Mesozoic and Paleogene substrata of the Pannonian basin is remarkable. The authors conclude that future exploration can be profitable provided that high technology is combined with adequate experience in post orogenic extensional terrains.

  6. Maps showing petroleum exploration intensity and production in major Cambrian to Ordovician reservoir rocks in the Anadarko Basin

    USGS Publications Warehouse

    Henry, Mitch; Hester, Tim

    1996-01-01

    The Anadarko basin is a large, deep, two-stage Paleozoic basin (Feinstein, 1981) that is petroleum rich and generally well explored. The Anadarko basin province, a geogrphic area used here mostly for the convenience of mapping and data management, is defined by political boundaries that include the Anadarko basin proper. The boundaries of the province are identical to those used by the U.S. Geological Survey (USGS) in the 1995 National Assessment of United Stated Oil and Gas Resources. The data in this report, also identical to those used in the national assessment, are from several computerized data bases including Nehring Research Group (NRG) Associates Inc., Significant Oil and Gas Fields of the United States (1992); Petroleum Information (PI), Inc., Well History Control System (1991); and Petroleum Information (PI), Inc., Petro-ROM: Production data on CD-ROM (1993). Although generated mostly in response to the national assessment, the data presented here arc grouped differently and arc displayed and described in greater detail. In addition, the stratigraphic sequences discussed may not necessarily correlate with the "plays" of the 1995 national assessment. This report uses computer-generated maps to show drilling intensity, producing wells, major fields, and other geologic information relevant to petroleum exploration and production in the lower Paleozoic part of the Anadarko basin province as defined for the U.S. Geological Survey's 1995 national petroleum assessment. Hydrocarbon accumulations must meet a minimum standard of 1 million barrels of oil (MMBO) or 6 billion cubic feet of gas (BCFG) estimated ultimate recovery to be included in this report as a major field or revoir. Mapped strata in this report include the Upper Cambrian to Lower Ordovician Arbuckle and Low Ordovician Ellenburger Groups, the Middle Ordovician Simpson Group, and the Middle to Upper Ordovician Viola Group.

  7. Debris-Flow Hazards within the Appalachian Mountains of the Eastern United States

    USGS Publications Warehouse

    Wieczorek, Gerald F.; Morgan, Benjamin A.

    2008-01-01

    Tropical storms, including hurricanes, often inflict major damage to property and disrupt the lives of people living in coastal areas of the Eastern United States. These storms also are capable of generating catastrophic landslides within the steep slopes of the Appalachian Mountains. Heavy rainfall from hurricanes, cloudbursts, and thunderstorms can generate rapidly moving debris flows that are among the most dangerous and damaging type of landslides. This fact sheet explores the nature and occurrence of debris flows in the central and southern Appalachian Mountains, which extend from central Pennsylvania to northern Alabama.

  8. Fragmenting and Reconstructing Identity: Struggles of Appalachian Women Attempting To Reconnect to Their Native American Heritage.

    ERIC Educational Resources Information Center

    Trollinger, Linda Burcham

    This qualitative study drew on the stories and reflections of six Appalachian women of Native American descent to explore their experiences of reconnecting with their lost Native identity. This paper visualizes those experiences in light of the relationships between personal realities and structural influences. Historically, Native identities have…

  9. Petroleum geology of Campos Basin, Brazil: A successful case history of deep water exploration

    SciTech Connect

    Franke, M.R.; Lugon, H.A.F.; Beraldo, W.L. )

    1990-05-01

    Campos Basin, the most prolific Brazilian basin, produces almost 400,000 bbl of oil per day and contains 70% of the national reserves. The basin is located on the southeastern coast of Brazil, covering a prospectable area of 100,000 km{sup 2} Campos is a passive continental margin basin originated by the breakup of Pangea and the rifting of the South American and African plates in the Early Cretaceous. The basin's sedimentary section encompasses three megasequences: nonmarine, transitional, and marine, ranging in age from Neocomian to Holocene. Hydrocarbon generation is related to nonmarine organic-rich shales and marls, and hydrocarbon entrapment assumes ascendent migration along fault planes and through salt gaps toward reservoirs ranging in age from Neocomian to Tertiary (mainly turbiditic sandstones). The first onshore stratigraphic well was drilled based on gravity surveys in 1958. The acquisition of new geophysical data, mainly seismic reflection data, followed after 1968. The first offshore well was drilled in 1971, and in 1974, the first oil field, Garopua, was discovered. Giant hydrocarbon accumulations have been discovered in water depths ranging from 400 to 1,800 m since 1984. As of mid-1989, 35 offshore oil fields have been discovered, 760 million bbl of oil, and 490 bcf of gas have been produced. The basin oil and equivalent gas reserves are estimated in 6.0 billion bbl, 60% of which is located in the deep-water giant oil fields.

  10. Giant polygons and circular graben in western Utopia basin, Mars: Exploring possible formation mechanisms

    NASA Astrophysics Data System (ADS)

    Buczkowski, Debra L.; Seelos, Kim D.; Cooke, Michele L.

    2012-08-01

    Large-scale fracture systems surrounding the Utopia basin include giant polygons and circular graben. Data covering the northern Utopia basin now allow high-resolution mapping of these features in all regions of the basin. Giant polygons to the north and south of the basin are different in both size and morphology, leading to the polygon classifications (1) S-style, (2) subdued S-style, (3) northern S-style and (4) N-style. Also, ten circular graben have been identified to the north of the Utopia basin. These have generally larger diameters than southern circular graben, and their fracture morphology is similar to N-style giant polygons. As with southern circular graben, the surface relief of the depression inside the northern circular graben scales directly with diameter. However, northern circular graben have less steep trend slopes, larger average diameters and greater ring spacing compared to southern circular graben of the same diameter and similar distance to the center of the Utopia basin. Both the giant polygons and circular graben of Utopia Planitia are consistent with formation by volumetric compaction of a fine-grained sedimentary material covering an uneven buried surface. Giant polygon size variations can be explained by the material being wet to the south but frozen or partially frozen to the north, while differences between northern and southern circular graben may be attributed to changes in cover thickness. Differences in fracture morphology can be explained by subsequent alteration of the northern troughs due to polar processes.

  11. Geologic atlas and database of major Appalachian gas plays

    SciTech Connect

    Patchen, D.G.; Nuttall, B.C.; Baranoski, M.T.; Harper, J.A.; Schwietering, J.F.; Van Tyne, A.; Aminian, K.; Smosna, R.A.

    1992-06-01

    The Appalachian Oil and Natural Gas Research Consortium (AONGRC or the Consortium) through a cooperative agreement with the US Department of Energy (DOE), will develop an atlas of major Appalachian gas plays and a machine readable database containing information about these plays. The specific objectives are to: define major gas plays in the basin by age and formation/group and then further by subdividing these units by reservoir rock trap type and depositional environments; determine and map all pools that are in each play; determine data to be collected and published for each pool; conduct a literature search for published and unpublished reservoir data, maps, cross sections, decline curves, and seismic profiles; utilize databases residing of state surveys to produce maps for key fields not available in literature; analyze cores and logs for key fields where these data are not available; redraft available maps and cross sections, compile tables of field data, and layout the atlas pages, including text; arrange the publication of the atlas; and deliver a machine readable database to the Department of Energy.

  12. Geologic atlas and database of major Appalachian gas plays

    SciTech Connect

    Patchen, D.G.; Nuttall, B.C.; Baranoski, M.T.; Harper, J.A.; Schwietering, J.F.; Van Tyne, A.; Aminian, K.; Smosna, R.A.

    1992-01-01

    The Appalachian Oil and Natural Gas Research Consortium (AONGRC or the Consortium) through a cooperative agreement with the US Department of Energy (DOE), will develop an atlas of major Appalachian gas plays and a machine readable database containing information about these plays. The specific objectives are to: define major gas plays in the basin by age and formation/group and then further by subdividing these units by reservoir rock trap type and depositional environments; determine and map all pools that are in each play; determine data to be collected and published for each pool; conduct a literature search for published and unpublished reservoir data, maps, cross sections, decline curves, and seismic profiles; utilize databases residing of state surveys to produce maps for key fields not available in literature; analyze cores and logs for key fields where these data are not available; redraft available maps and cross sections, compile tables of field data, and layout the atlas pages, including text; arrange the publication of the atlas; and deliver a machine readable database to the Department of Energy.

  13. The Status of Health Care in Appalachian Kentucky. Appalachian Data Bank Report #4.

    ERIC Educational Resources Information Center

    Bagby, Jane W.; And Others

    In the early 1960's, the Appalachian Regional Commission (ARC) established a goal to make health care more accessible to the people of the mountains. Today, a primary health care facility is within a 30 minute drive of nearly all Appalachian counties. There has also been a substantial, but still inadequate increase in health care professionals in…

  14. Cooperative Educational Project - The Southern Appalachians: A Changing World

    NASA Astrophysics Data System (ADS)

    Clark, S.; Back, J.; Tubiolo, A.; Romanaux, E.

    2001-12-01

    The Southern Appalachian Mountains, a popular recreation area known for its beauty and rich biodiversity, was chosen by the U.S. Geological Survey as the site to produce a video, booklet, and teachers guide to explain basic geologic principles and how long-term geologic processes affect landscapes, ecosystems, and the quality of human life. The video was produced in cooperation with the National Park Service and has benefited from the advice of the Southern Appalachian Man and Biosphere Cooperative, a group of 11 Federal and three State agencies that works to promote the environmental health, stewardship, and sustainable development of the resources of the region. Much of the information in the video is included in the booklet. A teachers guide provides supporting activities that teachers may use to reinforce the concepts presented in the video and booklet. Although the Southern Appalachians include some of the most visited recreation areas in the country, few are aware of the geologic underpinnings that have contributed to the beauty, biological diversity, and quality of human life in the region. The video includes several animated segments that show paleogeographic reconstructions of the Earth and movements of the North American continent over time; the formation of the Ocoee sedimentary basin beginning about 750 million years ago; the collision of the North American and African continents about 270 million years ago; the formation of granites and similar rocks, faults, and geologic windows; and the extent of glaciation in North America. The animated segments are tied to familiar public-access localities in the region. They illustrate geologic processes and time periods, making the geologic setting of the region more understandable to tourists and local students. The video reinforces the concept that understanding geologic processes and settings is an important component of informed land management to sustain the quality of life in a region. The video and a

  15. Preconception health indicators: a comparison between non-Appalachian and Appalachian women.

    PubMed

    Short, Vanessa L; Oza-Frank, Reena; Conrey, Elizabeth J

    2012-12-01

    To compare preconception health indicators (PCHIs) among non-pregnant women aged 18-44 years residing in Appalachian and non-Appalachian counties in 13 U.S. states. Data from the 1997-2005 Behavioral Risk Factor Surveillance System were used to estimate the prevalence of PCHIs among women in states with ≥1 Appalachian county. Counties were classified as Appalachian (n = 36,496 women) or non-Appalachian (n = 88,312 women) and Appalachian counties were categorized according to economic status. Bivariate and multivariable logistic regression models examined differences in PCHIs among women by (1) Appalachian residence, and (2) economic classification. Appalachian women were younger, lower income, and more often white and married compared to women in non-Appalachia. Appalachian women had significantly higher odds of reporting Appalachian women in counties with weaker economies had significantly higher odds of reporting less education, no health insurance, <5 daily fruits/vegetables, overweight/obesity, and poor mental health compared to Appalachian women in counties with the strongest economies. For many PCHIs, Appalachian women did not fare as well as non-Appalachians. Interventions sensitive to Appalachian culture to improve preconception health may be warranted for this population.

  16. An evaluation of the suitability of ERTS data for the purposes of petroleum exploration. [Anadarko Basin in Oklahoma and Texas

    NASA Technical Reports Server (NTRS)

    Everett, J. R.; Petzel, G.

    1974-01-01

    This investigation was undertaken to determine the types and amounts of information valuable to petroleum exploration that are extractable from ERTS data and to determine the cost of obtaining the information from ERTS relative to costs using traditional or conventional means. In particular, it was desirable to evaluate this new petroleum exploration tool in a geologically well-known area in order to assess its potential usefulness in an unknown area. In light of the current energy situation, it is felt that such an evaluation is important in order to best utilize technical efforts with customary exploration tools, by rapidly focusing attention on the most promising areas in order to reduce the time required to go through the exploration cycle and to maximize cost savings. The Anadarko Basin lies in western Oklahoma and the panhandle of Texas (Figure 1). It was chosen as a test site because there is a great deal of published information available on the surface and subsurface geology of the area, there are many known structures that act as traps for hydrocarbons, and it is similar to several other large epicontinental sedimentary basins.

  17. Exploration for deep gas in the Devonian Chaco Basin of Southern Bolivia: Sequence stratigraphy, predictions, and well results

    SciTech Connect

    Williams, K.E.; Radovich, B.J.; Brett, J.W.

    1995-12-31

    In mid 1991, a team was assembled in Texaco`s Frontier Exploration Department (FED) to define the hydrocarbon potential of the Chaco Basin of Southern Bolivia. The Miraflores No. 1 was drilled in the fall of 1992, for stratigraphic objectives. The well confirmed the predicted stratigraphic trap in the Mid-Devonian, with gas discovered in two highstand and transgressive sands. They are low contrast and low resistivity sands that are found in a deep basin `tight gas` setting. Testing of the gas sands was complicated by drilling fluid interactions at the well bore. Subsequent analysis indicated that the existing porosity and permeability were reduced, such that a realistic test of reservoir capabilities was prevented.

  18. Tectono-thermal History of the Southern Nenana Basin, Interior Alaska: Implications for Conventional and Unconventional Hydrocarbon Exploration

    NASA Astrophysics Data System (ADS)

    Dixit, N. C.; Hanks, C. L.

    2014-12-01

    The Tertiary Nenana basin of Interior Alaska is currently the focus of both new oil exploration and coalbed methane exploitation and is being evaluated as a potential CO2sequestration site. The basin first formed as a Late Paleocene extensional rift with the deposition of oil and gas-prone, coal-bearing non-marine sediments with excellent source potential. Basin inversion during the Early Eocene-Early Oligocene times resulted in folding and erosion of higher stratigraphic levels, forming excellent structural and stratigraphic traps. Initiation of active faulting on its eastern margin in the middle Oligocene caused slow tectonic subsidence that resulted in the deposition of reservoir and seal rocks of the Usibelli Group. Onset of rapid tectonic subsidence in Pliocene that continues to the present-day has provided significant pressure and temperature gradient for the source rocks. Apatite fission-track and vitrinite reflectance data reveals two major paleo-thermal episodes: Late Paleocene to Early Eocene (60 Ma to 54.8 Ma) and Late Miocene to present-day (7 Ma to present). These episodes of maximum paleotemperatures have implications for the evolution of source rock maturity within the basin. In this study, we are also investigating the potential for coalbed methane production from the Late Paleocene coals via injection of CO2. Our preliminary analyses demonstrate that 150 MMSCF of methane could be produced while 33000 tonnes of CO2 per injection well (base case of ~9 years) can be sequestered in the vicinity of existing infrastructure. However, these volumes of sequestered CO2and coal bed methane recovery are estimates and are sensitive to the reservoir's geomechanical and flow properties. Keywords: extensional rift, seismic, subsidence, thermal history, fission track, vitrinite reflectance, coal bed methane, Nenana basin, CO2 sequestration

  19. THE EFFECT OF APPALACHIAN MOUNTAINTOP MINING ON INTERIOR FOREST

    EPA Science Inventory

    Southern Appalachian forests are predominantly interior because they are spatially extensive with little disturbance imposed by other uses of the land. Appalachian mountaintop mining increased substantially during the 1990s, posing a threat to the interior character of the forest...

  20. Oil exploration and development in Marib/Al Jawf basin, Yemen Arab Republic

    SciTech Connect

    Maycock, I.D.

    1988-02-01

    In 1981, Yemen Hunt Oil Company (YHOC) negotiated a production-sharing agreement covering 12,600 km/sup 2/ in the northeast part of the Yemen Arab Republic. A reconnaissance seismic program of 1864 km acquired in 1982 revealed the presence of a major half graben, designated the Marib/Al Jawf basin by YHOC. A sedimentary section up to 18,000 ft thick has been recognized. Geologic field mapping identified Jurassic carbonates covered by Cretaceous sands overlying Permian glaciolacustrine sediments, Paleozoic sandstones, or Precambrian basement. The first well, Alif-1, drilled in 1984, aimed at a possible Jurassic carbonate objective, encountered hydrocarbon-bearing sands in the Jurassic-Cretaceous transition between 5000 and 6000 ft. Appraisal and development drilling followed. The Alif field is believed to contain in excess of 400 million bbl of recoverable oil. Subsequent wildcat drilling has located additional accumulations while further amplifying basin stratigraphy. Rapid basin development took place in the Late Jurassic culminating with the deposition of Tithonian salt. The evaporites provide an excellent seal for hydrocarbons apparently sourced from restricted basin shales and trapped in rapidly deposited clastics.

  1. Reinterpreting the Pinedale Anticline in the Green River Basin: Implications for future hydrocarbon exploration

    SciTech Connect

    Fagan, J.P. Jr.

    1996-06-01

    The Green River Basin is a northwest-southeast elongate structural feature located in southwestern Wyoming. Bounded by three basement uplifts, this complex mountain front basin possesses tremendous gas reserves. Production has been limited to a few structures, such as the Pinedale Anticline, because of the great depth of the basin. The Pinedale Anticline is an elongate structure that parallels the front of the Wind River Thrust. Earlier research has suggested that the anticline is not related to basement, but rather is associated with a foreland detachment structure. A new, high-resolution aeromagnetic survey has been modelled in detail and the results indicate that the Pinedale Anticline may actually be a basement related structure. Profile modelling normal to the anticline from the LaBarge Platform to the Wind River Mountains suggests that not only is Pinedale Field situated on a possible basement structure, but also that additional, heretofore unknown analogous features are also present in the basin. Additionally, an east-northeast structural grain is prevalent throughout the aeromagnetic dataset. This trend has been correlated with structures exposed in the Wind River Mountains and has also been shown to be important to locating hydrocarbon production. Thus, Cretaceous and Paleocene reactivation of Proterozoic age faults may have significantly affected location of structures, local stratigraphy and, subsequently, emplacement of hydrocarbons.

  2. Oil exploration and development in Marib/Al Jawf basin, Yemen Arab Republic

    SciTech Connect

    Maycock, I.D.

    1986-07-01

    In 1981, Yemen Hunt Oil Company (YHOC) negotiated a production-sharing agreement covering 12,600 km/sup 2/ in the northeast part of the Yemen Arab Republic. A reconnaissance seismic program of 1864 km acquired in 1982 revealed the presence of a major half graben, designated the Marib/Al Jawf basin by YHOC. A sedimentary section up to 18,000 ft thick has been recognized. Geologic field mapping identified Jurassic carbonates covered by Cretaceous sands overlying Permian glaciolacustrine sediments, Paleozoic sandstones, or Precambrian basement. The first well drilled in 1984, aimed at a possible Jurassic carbonate objective, encountered hydrocarbon-bearing sands in the Jurassic-Cretaceous transition between 5000 and 6000 ft. A successful appraisal drilling program has demonstrated satisfactory lateral reservoir continuity. Further wildcat drilling demonstrates macro-unit correlation within the eastern part of the basin. Rapid basin development apparently commenced in the late Kimmeridgian, culminating with the deposition of Tithonian evaporites. Available geochemical analysis indicates sourcing from restricted-basin sediments. Excellent traps, reservoirs, and source beds underlying the Tithonian evaporites indicate that a significant new petroliferous province is present.

  3. 1975 Annual Report of the Appalachian Regional Commission.

    ERIC Educational Resources Information Center

    Kendrick, Elise F., Ed,; And Others

    The Appalachian Regional Commission, created via the Regional Development Act of 1965, documents a decade of contributions to Appalachian socioeconomic development in this 1975 annual report. Topics covered in this report include: the ten years of foundation building; the Region before 1965; the Region and the Appalachian Regional Commission;…

  4. 3D modelling of an aero-gravity and -magnetic survey as an first exploration step in a frontier basin

    NASA Astrophysics Data System (ADS)

    Köther, Nils; Eckard, Marcel; Götze, Hans-Jürgen

    2010-05-01

    The West African Taoudeni basin covers a desert area of about 1.8 million km² and is one of the last frontier basins worldwide. Here Wintershall Holding AG holds acreage of about 68000 km². During 2005-2007 geological surveys and an aero-gravity and -magnetic survey were conducted in this area. The potential field modelling should contribute first insight about the subsurface to plan an economic seismic survey. 2D models lead to poor results. 2008 the results of an internship (NK) were 3D subsurface models, which were enhanced during the following diploma thesis (Köther, 2009). Complex igneous rocks and sparsely distributed constraints lead to an ambiguous interpretation. Therefore, several simple 3D models were compiled with the in-house software IGMAS+, which base on geological ideas of the underground and fit well the measured data. These basic models allow a geophysical evaluation of different geological theories about the subsurface. Also, for a thorough interpretation field transformations (Euler, Curvature, and Derivatives) were calculated. These results led to new constraints for further interpretation of the basin structures and therefore they are important contributions for future exploration e.g. the planning of seismic surveys.

  5. Exploring scale-dependent ecohydrological responses in a large endorheic river basin through integrated surface water-groundwater modeling

    NASA Astrophysics Data System (ADS)

    Tian, Yong; Zheng, Yi; Zheng, Chunmiao; Xiao, Honglang; Fan, Wenjie; Zou, Songbing; Wu, Bin; Yao, Yingying; Zhang, Aijing; Liu, Jie

    2015-06-01

    Ecohydrological processes in a water-limited environment are sensitive to both climate conditions and human activities, but the response mechanisms have rarely been explored for large endorheic river basins via an integrated modeling approach. This study established an integrated surface water-groundwater model for the Heihe River Basin (HRB), China's second largest endorheic river basin, using GSFLOW as the modeling platform. Evapotranspiration (ET) and Leaf Area Index (LAI) data independently derived from remote sensing products were compared and correlated, respectively, with the modeling results. Scale-dependent interrelationships among ecological, hydrological, and human-impact (i.e., diversion and pumping) variables were revealed through multiple regression analyses. Major study findings include: (1) the independent ET and LAI data enabled the modeler to crosscheck the modeling results from a unique angle not possible with conventional groundwater and streamflow observations; (2) controlling factors for the temporal variability of ET and LAI exhibit notable scale-dependence, reflecting distinctive climate, and human impacts on different land covers; and (3) there exists an intricate linkage between the hydrological regimes in the lower HRB and the middle HRB, essentially equivalent to a tradeoff between the ecosystem health of the lower HRB and the sustainable development of the middle HRB. Overall, the integrated modeling assisted by the independent ET and LAI data has provided a coherent understanding on the regional water cycle, and led to new insights on tackling the existing water conflicts in HRB.

  6. Appalachian Picturebooks, Read-Alouds, and Teacher-Led Discussion: Combating Stereotypes Associated with the Appalachian Region

    ERIC Educational Resources Information Center

    Brashears, Kathy

    2012-01-01

    The author's personal experiences indicate that, unfortunately, Appalachian culture in particular has been overlooked in many areas of literature and life. Major bookstores located in the Appalachian region frequently lack sections featuring Appalachian picturebooks. Her experiences with schools also indicate that living in Appalachia does not…

  7. Application of structures mapped from Landsat imagery to exploration for stratigraphic traps in Paradox basin

    SciTech Connect

    Merin, I.S.; Michael, R.C.

    1985-02-01

    Significant quantities of petroleum occur in algal buildups of Pennsylvanian age in the Paradox basin. Isopach and lithofacies mapping by others suggest that low-relief paleostructures appear to have controlled Pennsylvanian sea-floor topography and thus the distribution of the buildups. Several workers have reported that these paleostructures trend northwest and northeast. Therefore, the basin can be visualized as a mosaic of fault blocks that were differentially active through geologic time. The buildups are elongate northwest, and their distribution and overall shape appear to be controlled by northwest-trending paleostructures. Some larger buildups (i.e., Ismay) show local northeast-trending thicks within an overall northwest-trending buildup. Examination of Landsat imagery revealed an extensive network of northwest-and northeast-trending lineaments that parallel linear patterns apparent from aeromagnetic, gravity, and subsurface isopach data. Additionally, outcrops along selected lineaments contain fractures that parallel these lineaments, suggesting that the lineaments are related to fundamental (i.e., basement) fracture zones along which algal buildups may have developed. Comparison of the fracture network to the distribution of algal thickening reveals these buildups occur predominantly along northwest-trending lineaments. Local disruptions within and apparent terminations of the buildups correspond to cross-cutting northeast-trending lineaments. This relationship provides guidance to locating prospective algal buildups. Integration of these data with detailed subsurface mapping can refine some leads into prospects. Several of these features have been successfully drilled.

  8. Metals in water, sediments, and biota of an offshore oil exploration area in the Potiguar Basin, Northeastern Brazil.

    PubMed

    Lacerda, L D; Campos, R C; Santelli, R E

    2013-05-01

    Metal concentrations were evaluated in water, bottom sediments, and biota in four field campaigns from 2002 to 2004 in the Potiguar Basin, northeastern Brazil, where offshore oil exploration occurs. Analyses were performed by inductively coupled plasma mass spectrometry and inductively coupled plasma optical emission spectrometry. Total metal concentrations in water (dissolved + particulate) and sediments were in the range expected for coastal and oceanic areas. Abnormally high concentrations in waters were only found for Ba (80 μg l(-1)) and Mn (12 μg l(-1)) at the releasing point of one of the outfalls, and for the other metals, concentrations in water were found in stations closer to shore, suggesting continental inputs. In bottom sediments, only Fe and Mn showed abnormal concentrations closer to the effluent releasing point. Metal spatial distribution in shelf sediments showed the influence of the silt-clay fraction distribution, with deeper stations at the edge of the continental shelf, which are much richer in silt-clay fraction showing higher concentrations than shallower sediments typically dominated by carbonates. Metal concentrations in estuarine (mollusks and crustaceans) and marine (fish) organisms showed highest concentrations in oysters (Crassostrea rhizophorae). Fish tissues metal concentrations were similar between the continental shelf influenced by the oil exploration area and a control site. The results were within the range of concentrations reported for pristine environments without metals contamination. The global results suggest small, if any, alteration in metal concentrations due to the oil exploration activity in the Potiguar Basin. For monitoring purposes, the continental inputs and the distribution of the clay-silt fraction need to be taken into consideration for interpreting environmental monitoring results. PMID:23014923

  9. Examining substance use among rural Appalachian and urban non-Appalachian individuals participating in drug court.

    PubMed

    Shannon, Lisa M; Perkins, Elizabeth B; Neal, Connie

    2014-02-01

    The study purpose was to examine differences in substance use among individuals in drug court (N = 583) in rural Appalachian (n = 301) and urban non-Appalachian areas (n = 282). A series of logistic regression analyses suggested individuals in the rural Appalachian area were significantly more likely to report lifetime use of cocaine, illicit opiates, and illicit benzodiazepines, but they were less likely to report methamphetamine use when compared with individuals in the urban non-Appalachian area. Regarding past 30-day use, a series of logistic regression analyses suggested individuals in the rural Appalachian area were significantly more likely to use marijuana, illicit opiates, and illicit benzodiazepines, but they were less likely to report crack cocaine use when compared with individuals in the urban non-Appalachian area. Identifying differences which exist in substance use is the first step in generating evidence-based structural changes in treatment drug court programs. Future research should focus on better understanding context in terms of demographic, geographic, and economic conditions, which may be of critical influence on substance use and treatment planning.

  10. A Human Exploration Zone on the East Rim of Hellas Basin, Mars: Mesopotamia

    NASA Astrophysics Data System (ADS)

    Gallegos, Z. E.; Newsom, H. E.

    2015-10-01

    This abstract highlights a previously unexplored area in the Hellas Planitia region of Mars. The exploration zone proposed offers scientifically compelling regions of interest, as well as abundant resources for reoccurring human missions.

  11. Appalachian Regional Commission Annual Report, 2000.

    ERIC Educational Resources Information Center

    Appalachian Regional Commission, Washington, DC.

    In 2000, the Appalachian Regional Commission (ARC), in cooperation with local development districts, nonprofit organizations, and many small municipalities, expanded programs to help Appalachia's distressed counties become economically competitive. The effort calls for increased funding for technical assistance and capacity building in distressed…

  12. Appalachian Regional Commission: 1981 Annual Report.

    ERIC Educational Resources Information Center

    Appalachian Regional Commission, Washington, DC.

    Although fiscal year 1981 was a time of uncertainty for the Appalachian Regional Commission (ARC), Congress did appropriate $218.2 million for the highway program and $87 million for area development, research and local development districts (LDDs), and administrative costs. Coupled with other federal funds and funds from state and local sources,…

  13. ALCOR: Appalachian People Helping Each Other.

    ERIC Educational Resources Information Center

    Burch, Jack E., Jr.; Cox, L. James

    1978-01-01

    Describes a student service-learning program in the Cumberland Mountains in southeastern Kentucky called Appalachian Leadership and Community Outreach (ALCOR). ALCOR provides various community services in 20 counties with six mountain colleges and private and public organizations. Several ALCOR colleges give academic credit for the ALCOR learning.…

  14. Black Populations of the Southern Appalachian Mountains.

    ERIC Educational Resources Information Center

    Stuckert, Robert P.

    1987-01-01

    Few books have been written and little information is known about Black populations of the southern Appalachian mountains. This article describes the cultural and settlement patterns of these people and traces their historical development. Occupational changes and the effects of urbanization are presented. (VM)

  15. Panel V: Displaced Workers: Appalachian Case Studies.

    ERIC Educational Resources Information Center

    Appalachia, 1984

    1984-01-01

    Discussions centered on circumstances faced by laid-off workers in Portsmouth, Ohio, Pittsburgh, Pennsylvania, Upper Cumberland, Tennessee, and Gary, West Virginia. These diverse Appalachian communities are prototypes of the extent of local distress imposed by the impersonal workings of the market and the absence of precedents for dealing with…

  16. Writing at One Appalachian High School

    ERIC Educational Resources Information Center

    Iddings, Joshua Glenn

    2013-01-01

    The purpose of this study was to investigate twelfth grade writing instruction at one high school in the Northeastern Kentucky Appalachian region. At the time of the study, Kentucky schools were in a pivotal transitional period as they were adopting the Common Core State Standards while also removing the mandatory portfolio-based writing…

  17. Appalachian Regional Commission Annual Report, 2001.

    ERIC Educational Resources Information Center

    Appalachian Regional Commission, Washington, DC.

    In fiscal year 2001, the Appalachian Regional Commission invested $63.6 million in 469 economic and human development (nonhighway) projects and $389.6 million in highway projects in Appalachia. The Commission launched a new initiative to promote the development of telecommunications infrastructure, especially in distressed counties. The Commission…

  18. The Appalachian Education Satellite Project Final Report.

    ERIC Educational Resources Information Center

    Appalachian Education Satellite Project, Lexington, KY.

    The first section of this report describes the objectives, project organization, and program of the Appalachian Education Satellite Project. The second section describes the resource coordinating centers and their seven missions: reading course development, career education course development for K-6 and 7-12, four-channel audio program…

  19. Energy Drink Use Among Ohio Appalachian Smokers.

    PubMed

    Davison, Genevieve; Shoben, Abigail; Pasch, Keryn E; Klein, Elizabeth G

    2016-10-01

    Caffeine-containing energy drinks have emerged as a public health concern due to their association with caffeine toxicity and alcohol use. Despite the fact that previous research has linked caffeine use in the form of coffee drinking to smoking, there is little research examining the association between energy drinks and smoking. The present study examines demographic and behavioral factors associated with energy drink use among a sample of rural Ohio Appalachian smokers. It was hypothesized that male gender, young age (21-30 years.) and alcohol use would be associated with energy drink use. A sample of adult smokers (n = 298) from Ohio Appalachian counties were interviewed regarding demographic and behavioral factors. Logistic regression analysis was used to assess the association between these factors and energy drink use. Seventy percent of Ohio Appalachian smokers studied had ever used an energy drink and 40 % had used an energy drink in the past month. Young age, male gender, and single marital status were associated with higher odds of ever having used an energy drink. Young age, and binge drinking were associated with higher odds of past 30-day use while abstinence from drinking was associated with lower odds of past 30-day use. Ohio Appalachian adult smokers had higher rates of energy drink use compared to previous estimates of ever or past month use found in other studies. The combined use of caffeine, nicotine, and alcohol warrants attention due to potential for health risk.

  20. Appalachian Parents' Expectations of Child Competencies.

    ERIC Educational Resources Information Center

    Shively, Joe E.

    This report describes a survey of Appalachian parents conducted to determine what abilities they expect their children to develop before entrance into first grade. The survey was designed to help establish an empirical base for the curriculum of Appalachia Educational Laboratory's Home-Oriented Preschool Education Program (HOPE). HOPE is an…

  1. Sugar in the Gourd: Preserving Appalachian Traditions.

    ERIC Educational Resources Information Center

    Brown, Tom

    1983-01-01

    The Appalachian Folk Music Project developed methods to teach folk music in the schools. Authentic material was identified and teaching methods appropriate to rural Appalachia were selected. Departures from the norm included teaching of instruments like the dulcimer, harmonica, and fiddle and the use of folk models whenever possible. (CS)

  2. Rod Soltis: Making Connections. Appalachian Scene.

    ERIC Educational Resources Information Center

    Baldwin, Fred D.

    1998-01-01

    Describes the work of Rod Soltis in developing interlinked telecommunications networks in all 14 of New York's Appalachian counties. The networks connect to each other, state and federal agencies and networks, schools, social service agencies, hospitals, and museums, and include private partnerships with telephone and cable TV companies. Soltis'…

  3. Colonialism in Modern America: The Appalachian Case.

    ERIC Educational Resources Information Center

    Lewis, Helen Matthews, Ed.; And Others

    The essays in this book illustrate a conceptual model for analyzing the social and economic problems of the Appalachian region. The model is variously called Colonialism, Internal Colonialism, Exploitation, or External Oppression. It highlights the process through which dominant outside industrial interests establish control, exploit the region,…

  4. Energy Drink Use Among Ohio Appalachian Smokers.

    PubMed

    Davison, Genevieve; Shoben, Abigail; Pasch, Keryn E; Klein, Elizabeth G

    2016-10-01

    Caffeine-containing energy drinks have emerged as a public health concern due to their association with caffeine toxicity and alcohol use. Despite the fact that previous research has linked caffeine use in the form of coffee drinking to smoking, there is little research examining the association between energy drinks and smoking. The present study examines demographic and behavioral factors associated with energy drink use among a sample of rural Ohio Appalachian smokers. It was hypothesized that male gender, young age (21-30 years.) and alcohol use would be associated with energy drink use. A sample of adult smokers (n = 298) from Ohio Appalachian counties were interviewed regarding demographic and behavioral factors. Logistic regression analysis was used to assess the association between these factors and energy drink use. Seventy percent of Ohio Appalachian smokers studied had ever used an energy drink and 40 % had used an energy drink in the past month. Young age, male gender, and single marital status were associated with higher odds of ever having used an energy drink. Young age, and binge drinking were associated with higher odds of past 30-day use while abstinence from drinking was associated with lower odds of past 30-day use. Ohio Appalachian adult smokers had higher rates of energy drink use compared to previous estimates of ever or past month use found in other studies. The combined use of caffeine, nicotine, and alcohol warrants attention due to potential for health risk. PMID:26879965

  5. Appalachian Regional Commission: 1987 Annual Report.

    ERIC Educational Resources Information Center

    Russell, Jack, Ed.; And Others

    The Appalachian Regional Commission (ARC) used its $105 million appropriation for fiscal year 1987 to support three major program areas in the 13 state region: (1) creating and retaining regional jobs; (2) assisting in construction of basic facilities, particularly water and sewer systems, in the region's 90 poorest counties; and (3) working…

  6. “It's Just a Way of Fitting In:” Tobacco Use and the Lived Experience of Lesbian, Gay, and Bisexual Appalachians

    PubMed Central

    Bennett, Keisa; Ricks, JaNelle M.; Howell, Britteny M.

    2014-01-01

    Lesbian, gay, and bisexual (LGB) people are affected by multiple health disparities and risk factors, including tobacco use. Few studies to date have examined tobacco use specifically in rural LGB populations, and none has investigated the intersections of identity, rural LGB culture, and tobacco. The purpose of this study was to explore the perspective of Appalachian LGB people regarding tobacco use. Methods Nineteen LGB-identified Appalachian residents participated in audiotaped, semi-structured interviews. Two authors analyzed and coded transcripts through constant comparison, and determined themes through consensus. Results Five themes emerged: the convergence of Appalachian and LGB identities, tacit awareness of LGB identity by others, culture and tobacco use, perceived associations with tobacco use, and health beliefs and health care. Conclusions LGB Appalachians connect stress and culture to tobacco, but seem less aware that partial concealment of their identity might be a source of the stress that could influence their smoking. PMID:25418233

  7. Discovery of a concealed geothermal resource in the Alturas Basin, and its implications for further exploration in northeastern California

    SciTech Connect

    Bohm, B.; Juncal, R.W.

    1995-12-31

    In 1988 a so far unknown geothermal resource was drilled into under the City of Alturas in northeastern California. A fracture was tapped below 2300 feet, in cemented fine-grained tuffs and mudflows, producing 182{degrees}F water. The well has been used since 1990 to heat the local high school. A second well was drilled in 1991, producing about 250 gpm 182{degrees}F water from a fracture below 1893 ft. Well productivities and artesian pressures are variable, depending on distance from a major fault zone and local hydrologic regime. It appears as if the wells produce from deep reaching fractures in a caprock, that may conceal a 300 to 400{degrees}F resource between 4000 and 6000 feet depth. The results have important implications for geothermal exploration in northeastern California, i.e. just because there are no surface manifestations in a basin, it does not necessarily mean there is no geothermal resource at depth.

  8. Integrated analysis of high resolution aeromagnetic and satellite imagery data for hydrocarbon exploration in frontier and mature basins

    SciTech Connect

    Berger, Z.; Nash, C.; Ellis, C.; Witham, B.

    1996-08-01

    Recent improvement in the collection and processing of high resolution aeromagnetic data provides, for the first time, information on the spatial distribution of geological structures in the sedimentary section. The magnetic data, which is presented with a series of color images, can be easily merged and correlated with satellite imagery data, air and space home radar and conventional aerial photography. The integration of these two different reconnaissance tools provides excellent means for structural mapping and early evaluation of hydrocarbon plays in both frontier and mature areas. A series of examples supported by both surface and subsurface controls are used to illustrate the exploration application of these two different data sets. In the frontier fold and thrust belts regions of the North Slope Alaska, the Andes of South America, and the Canadian Foothills, high resolution magnetic images and side-looking air and space borne radar data are effectively used to improve the interpretation of geological structures above the detachment levels. This data was also used to identify the presence of basement involved reactivated structures and related migration pathways. In less deformed and more mature areas, such as the Central Basin Platform of West Texas and the Peace River Arch of the Western Canada Basin, the integration of high resolution magnetic images and Landsat TM data leads to the recognition of new faults and fracture systems and related hydrocarbon plays. The availability of high resolution magnetic surveys and new space borne radar systems such as ERS-1, JERS-1 and RADARSAT should play a significant role in exploration of the heavily vegetated fold belt regions of the tropics as well as the vast plains and plateaus of the South American continent.

  9. Estimating exploration potential in mature producing area, northwest shelf of Delaware Basin, New Mexico

    SciTech Connect

    Kumar, N.

    1985-11-01

    The case history presented here describes an investigation of the Northwest shelf of the Delaware basin carried out in 1979 for estimating the potential of finding new reserves and a follow-up study to measure predictions against results. A total of 191 new-field wildcats had been drilled during 1974-1979 in the study area. An analysis of target zones and success ratios showed that the best chances of drilling a successful test were in the San Andres (Permian) and Silurian-Devonian. However, cumulative frequency plots of existing fields in these two intervals showed that the chance of finding a field larger than 1 million bbl (159,000 m/sup 3/) in either of these zones was relatively low. As a result of the 1979 analysis, three prospective areas representing 8% of the total study area were high graded, or rated as having a higher potential than other parts of the study area. The 1980-1983 drilling results show that the original high-graded areas contain 52% of the 21 successful San Andres tests and the only discovery in the Silurian-Devonian. However, as predicted by the analysis, all of these discoveries appear to be small. 12 figures, 2 tables.

  10. Exploring the effectiveness of sustainable water management structures in the Upper Pungwe river basin

    NASA Astrophysics Data System (ADS)

    Nyikadzino, B.; Chibisa, P.; Makurira, H.

    The study endeavoured to assess the effectiveness of stakeholder structures and their participation in sustainable water resources management in the Upper Pungwe river basin shared by Zimbabwe and Mozambique. The study sought to assess the level and effectiveness of stakeholder, gender and the vulnerable groups representation in sustainable water resources management as well as the whole stakeholder participation process. The study employed both qualitative and quantitative methods for data collection and analysis. Sampling data was obtained from 15 stakeholder representatives (councillors) constituting Pungwe Subcatchment Council, 30 water users ranging from small scale to large scale users and professionals in water resources management. Two different questionnaires and three structured interviews were administered during the study. Water permit database, financial reports and other source documents were also analysed. The study established that the sustainability and effectiveness of stakeholder structures and their participation in water resources management is being compromised by lack of stakeholder awareness. Water utilisation is very high in the subcatchment (99%) while women participation is still low (20%). The study therefore recommends the use of quotas for the participation of women in stakeholder structures. Stakeholder structures are encouraged to intensify stakeholder awareness on issues of river protection, efficient water use and pollution control. Further research is recommended to be carried out on the effectiveness of stakeholder structures in combating water pollution and enhancing river protection.

  11. Geothermal exploration assessment and interpretation, Upper Klamah Lake Area, Klamath Basin, Oregon

    SciTech Connect

    Stark, M.; Goldstein, N.E.; Wollenberg, H.A.

    1980-09-01

    Data from public and private sources on the Klamath Basin geothermal resource are reviewed, synthesized, and reinterpreted. In this, the second and final phase of the work, geological, remote sensing, geochemical, temperature gradient, gravity, aeromagnetic, and electrical resistivity data sets are examined. These data were derived from surveys concentrated on the east and west shores of Upper Klamath Lake. The geological, remote sensing, and potential field data suggest a few northeast-trending discontinuities, which cross the regional north-westerly strike. The near-surface distribution of warm water appears to be related to the intersections of these lineaments and northwest-trending faults. The groundwater geochemical data are reviewed and the various reservoir temperature estimates compared. Particular attention is given to specific electrical conductivities of waters as an interpretational aid to the subsurface resistivity results. A clear trend emerges in the Klamath Falls/Olene Gap area; hotter waters are associated with higher specific conductivities. In the Nuss Lake/Stukel Mountain area the opposite trend prevails, although the relationship is somewhat equivocal.

  12. Southern Appalachian hillslope erosion rates measured by soil and detrital radiocarbon in hollows

    USGS Publications Warehouse

    Hales, T.C.; Scharer, K.M.; Wooten, R.M.

    2012-01-01

    Understanding the dynamics of sediment generation and transport on hillslopes provides important constraints on the rate of sediment output from orogenic systems. Hillslope sediment fluxes are recorded by organic material found in the deposits infilling unchanneled convergent topographic features called hollows. This study describes the first hollow infilling rates measured in the southern Appalachian Mountains. Infilling rates (and bedrock erosion rates) were calculated from the vertical distribution of radiocarbon ages at two sites in the Coweeta drainage basin, western North Carolina. At each site we dated paired charcoal and silt soil organic matter samples from five different horizons. Paired radiocarbon samples were used to bracket the age of the soil material in order to capture the range of complex soil forming processes and deposition within the hollows. These dates constrain hillslope erosion rates of between 0.051 and 0.111mmyr-1. These rates are up to 4 times higher than spatially-averaged rates for the Southern Appalachian Mountains making creep processes one of the most efficient erosional mechanisms in this mountain range. Our hillslope erosion rates are consistent with those of forested mountain ranges in the western United States, suggesting that the mechanisms (dominantly tree throw) driving creep erosion in both the western United States and the Southern Appalachian Mountains are equally effective. ?? 2011 Elsevier B.V.

  13. Vertical movements of crust, uplift of lithosphere, and isostatic unroofing: case histories from the Ozark dome and northern Appalachians

    SciTech Connect

    Friedman, G.M.

    1987-05-01

    Evidence of former deep burial of Ordovician to Devonian strata of the Ozark dome and northern Appalachians has been obtained from petrographic and geochemical studies of carbonates and coal-bearing rocks. In diagenetic minerals of the carbonate rocks, fluid inclusion homogenization temperatures and delta/sup 18/O values indicate paleotemperatures of 100 to 200/sup 0/C. The geothermometers used also include vitrinite reflectance, level of organic metamorphism (LOM), Staplin kerogen alteration index, and conodont alteration index (CAI). Maximum depths of burial were calculated from the estimated paleotemperatures assuming a geothermal gradient of about 25/sup 0/C/km. Strata of the Silurian of the northern Appalachian basin and of the Ordovician of the Ozark dome are interpreted to have reached maximum burial depths of 5 and 4.3 km, respectively; Devonian strata in the Catskill Mountains of New York had former burial depths of about 6.5 km; Lower Ordovician carbonate sequences of the northern Appalachian basin were buried to more than 7 km; Middle Ordovician strata from the same basin had paleodepths of approximately 5 km, and Devonian strata, 4.5 to 5 km. If these strata were formerly buried much more deeply than previously thought, then unexpectedly large amounts of uplift and erosion, ranging from 4.3 to 7 km, must also have occurred to bring these strata to the present land surface. The occurrence of such large-scale vertical movements of the crust and lithosphere needs to be recognized in paleogeographic reconstructions.

  14. A-D. Evolution of sedimentary basins

    SciTech Connect

    Not Available

    1988-01-01

    This book includes the first four chapters in a bulletin series on the evolution of the Appalachian Basin. Structural, tectonic, sedimentologic, and conodont color alteration studies are presented, and the implications of the results of these studies on hydrocarbon potential in the area are discussed.

  15. Subsurface temperature as a passkey for exploration of mature basins: Hot anticlines - A key to discovery?

    USGS Publications Warehouse

    Merriam, D.F.

    2004-01-01

    Temperature anomalies associated with oil-producing structures in the US Midcontinent and similar cratonic areas probably can be used reliably as a passkey for petroleum exploration in mature areas, and thus the concept of hot anticlines could be a key to discovery. Analysis of accumulated data during the past several decades allows a definition of the problem of hot anticlines. A possible solution for migration and entrapment of petroleum can be explained by the Roberts temperature differential model and the Walters fluid-flow paradigm. In fact, if the Roberts model is valid, higher shallow temperatures, temperature gradients, or heat flow could indicate the entrapment of hydrocarbons at depth. The recognition and promotion of shallow "hotspots" as an exploration key is not new and was proposed years ago by Haas and Hoffmann, Kappelmeyer, and as recently as 1986 by Blackwell.

  16. Exploration

    USGS Publications Warehouse

    Wilburn, D.R.

    2001-01-01

    Part of an annual review of mines and mineral resources in the U.S. An overview of nonfuel-mineral exploration in 2000 is presented. Principal exploration target was gold exploration in Latin America, Australia, and the U.S. There was a decrease of 18 percent in the exploration budget for gold as compared with the budget for 1999. Statistical information on nonfuel-mineral exploration worldwide is presented, analyzed, and interpreted.

  17. Time perspective and physical activity among central Appalachian adolescents.

    PubMed

    Gulley, Tauna

    2013-04-01

    Time perspective is a cultural behavioral concept that reflects individuals' orientations or attitudes toward the past, present, or future. Individuals' time perspectives influence their choices regarding daily activities. Time perspective is an important consideration when teaching adolescents about the importance of being physically active. However, little is known about the relationship between time perspective and physical activity among adolescents. The purpose of this study was to determine the time perspective of central Appalachian adolescents and explore the relationship between time perspective and physical activity. This study was guided by The theory of planned behavior (TPB). One hundred and ninety-three students completed surveys to examine time perspective and physical activity behaviors. Data were collected in one school. Results of this study can inform school nurses and high school guidance counselors about the importance of promoting a future-oriented time perspective to improve physical activity and educational outcomes.

  18. Early evolution of the southern margin of the Neuquén Basin, Argentina: Tectono-stratigraphic implications for rift evolution and exploration of hydrocarbon plays

    NASA Astrophysics Data System (ADS)

    D'Elia, Leandro; Bilmes, Andrés; Franzese, Juan R.; Veiga, Gonzalo D.; Hernández, Mariano; Muravchik, Martín

    2015-12-01

    Long-lived rift basins are characterized by a complex structural and tectonic evolution. They present significant lateral and vertical stratigraphic variations that determine diverse basin-patterns at different timing, scale and location. These issues cause difficulties to establish facies models, correlations and stratal stacking patterns of the fault-related stratigraphy, specially when exploration of hydrocarbon plays proceeds on the subsurface of a basin. The present case study corresponds to the rift-successions of the Neuquén Basin. This basin formed in response to continental extension that took place at the western margin of Gondwana during the Late Triassic-Early Jurassic. A tectono-stratigraphic analysis of the initial successions of the southern part of the Neuquén Basin was carried out. Three syn-rift sequences were determined. These syn-rift sequences were located in different extensional depocentres during the rifting phases. The specific periods of rifting show distinctly different structural and stratigraphic styles: from non-volcanic to volcanic successions and/or from continental to marine sedimentation. The results were compared with surface and subsurface interpretations performed for other depocentres of the basin, devising an integrated rifting scheme for the whole basin. The more accepted tectono-stratigraphic scheme that assumes the deposits of the first marine transgression (Cuyo Cycle) as indicative of the onset of a post-rift phase is reconsidered. In the southern part of the basin, the marine deposits (lower Cuyo Cycle) were integrated into the syn-rift phase, implying the existence of different tectonic signatures for Cuyo Cycle along the basin. The rift climax becomes younger from north to south along the basin. The post-rift initiation followed the diachronic ending of the main syn-rift phase throughout the Neuquén Basin. Thus, initiation of the post-rift stage started in the north and proceeded towards the south, constituting a

  19. Basin analysis and petroleum potential of Michigan Basin: deposition and subsidence history from Middle Ordovician (Trenton Formation) to Early Devonian

    SciTech Connect

    Nurmi, R.D.

    1984-12-01

    The history of the Michigan basin (Early Ordovician to Early Devonian) is that of a nonuniformly subsiding basin, with the Michigan basin, at times, nearly disappearing as either a topographic feature or a depositional center. This history is interpreted from the analysis of lithostratigraphic units, time stratigraphic features, and log formats (term by J. Forgotson). These units are defined for wells throughout the Michigan basin, and they extended eastward into the Appalachian basin. The definition and thickness mapping of these lithostratigraphic units and formats are accomplished using well cuttings, cores, and wire-line geophysical well logs. From these data, it is possible to interpret the major aspects of both the subsidence and depositional history of the basin. During deposition of both the Trenton limestones and Early Silurian carbonates and shales, the Michigan basin behaved as if it were part of the greater Appalachian basin, whereas prior to the deposition of the Trenton (Middle Ordovician) and during Middle and Late Silurian, the Michigan basin was an entity separate from, and with an apparent structural independence of, the greater Appalachian basin. The structural and topography of the Trenton prior to the deposition of the Utica Shale was mapped throughout Michigan to provide insight into the nature of petroleum entrapment in the Trenton formation. The structural entrapment of petroleum in southeast Michigan contrasts with the combination diagenetic to structural Albio-Scipio trend of south-central Michigan. Evidence is available that more of these two types of traps occur in unproducing areas of the Michigan basin.

  20. Origin of subpressure and hydrocarbon exploration in Shiwu fault depression, Songliao Basin, China

    SciTech Connect

    Zhou, Guojun )

    1994-08-01

    In the Shiwu fault depression, evolutionary history of formation pressure can be deduced on the basis of structural evolutionary history. Uplifting and denudation caused high pressure to evolve into low pressure. The main factors controlling the evolutions are (1) generation of fractures and release of high pressure, (2) temperature reduction and water-cooling pressure reduction, (3) desaturation and gas dissociation, and (4) diffusion and dissipation of gas. According to the pressure evolutionary history, the study area has had two pool-forming stages. During uplifting and denudation, fracture generation, and the transformation from high pressure to low pressure, the protogenic high-pressure oil and gas pools were transformed into low-pressure relic pools, and secondary pools with normal pressure formed above them. A predictor equation of the low pressure has been proposed on the basis of the balanced depth in the undercompaction zone, as well as the eroded thickness of the overlying strata. According to this equation, measured pressure data, well logs, and seismic interval velocity data, pressure prediction has been made in the study area by drawing on experience gained at key points. In the light of pressure evolutionary history and pool-forming history, it is regarded that the exploration potential of the low-pressure zone is not as good as that of the hydrostatic-pressure zone. This has been verified by petroleum exploration activities.

  1. Near Surface Geophysical Exploration at The Archaeological Site of San Miguel Tocuila, Basin of Mexico.

    NASA Astrophysics Data System (ADS)

    Arciniega, A.; Hernandez, E.; Cabral-Cano, E.; Diaz-Molina, O.; Morett, L.; Soler, A.

    2008-12-01

    The village of Tocuila is located on the western margin of Lake Texcoco in central Mexico. Volcanic activity during the Late Pleistocene and Early Holocene closed the basin's drainage and facilitated the development of a lacustrine environment and subsequent deposition of volcano-sedimentary sequences with abundant archaeological and paleontological record. Tocuila was one of the most prominent suburbs of the main civic ceremonial complex of the Aztecs. The rapid expansion of Mexico City's Metropolitan areas in the last three decades strongly influenced Tocuila's environment and has compromised several of its archaeological and ancient human settlements. A near surface geophysical survey including magnetometry, seismic refraction tomography and Ground Penetrating Radar (GPR) techniques was conducted to investigate pre-Hispanic structures. The magnetometric survey was performed using an Overhauser magnetometer with an omnidirectional, 0.015 nT/Hz sensor and 1Hz sampling rate over a 80x100 m area, yielding 990 measurements of total intensity magnetic field at 1.0m height above the ground surface. Thirty seismic refraction profiles were obtained with a 48-channel 24 bits Geometrics StrataVisor NZ seismograph, 14 Hz natural frequency vertical geophones with a 2m separation array and an impact source of 5 kg. The GPR survey consisted of 15 cross sections at two different resolutions with a GSSI SIR-3000 instrument, using a GSSI 200 MHz and a RadarTeam 70 MHz antennas. All surveys were georeferenced with a dual frequency GPS local station and a GPS rover attached to the surveying geophysical instruments. Seismic refraction tomography and GPR radargrams show a platform structure of approx. 80x60 m which can be subdivided in three distinctive layers with a total height of ~10m. Based on the history of ancient settlements in the area surrounding Lake Texcoco and considering the characteristics of shape and height of the surveyed structure, we interpreted that the resulting

  2. Megafaunal Community Structure of Andaman Seamounts Including the Back-Arc Basin – A Quantitative Exploration from the Indian Ocean

    PubMed Central

    Sautya, Sabyasachi; Ingole, Baban; Ray, Durbar; Stöhr, Sabine; Samudrala, Kiranmai; Raju, K. A. Kamesh; Mudholkar, Abhay

    2011-01-01

    Species rich benthic communities have been reported from some seamounts, predominantly from the Atlantic and Pacific Oceans, but the fauna and habitats on Indian Ocean seamounts are still poorly known. This study focuses on two seamounts, a submarine volcano (cratered seamount – CSM) and a non-volcano (SM2) in the Andaman Back–arc Basin (ABB), and the basin itself. The main purpose was to explore and generate regional biodiversity data from summit and flank (upper slope) of the Andaman seamounts for comparison with other seamounts worldwide. We also investigated how substratum types affect the megafaunal community structure along the ABB. Underwater video recordings from TeleVision guided Gripper (TVG) lowerings were used to describe the benthic community structure along the ABB and both seamounts. We found 13 varieties of substratum in the study area. The CSM has hard substratum, such as boulders and cobbles, whereas the SM2 was dominated by cobbles and fine sediment. The highest abundance of megabenthic communities was recorded on the flank of the CSM. Species richness and diversity were higher at the flank of the CSM than other are of ABB. Non-metric multi-dimensional scaling (nMDS) analysis of substratum types showed 50% similarity between the flanks of both seamounts, because both sites have a component of cobbles mixed with fine sediments in their substratum. Further, nMDS of faunal abundance revealed two groups, each restricted to one of the seamounts, suggesting faunal distinctness between them. The sessile fauna corals and poriferans showed a significant positive relation with cobbles and fine sediments substratum, while the mobile categories echinoderms and arthropods showed a significant positive relation with fine sediments only. PMID:21297959

  3. Megafaunal community structure of Andaman seamounts including the Back-arc Basin--a quantitative exploration from the Indian Ocean.

    PubMed

    Sautya, Sabyasachi; Ingole, Baban; Ray, Durbar; Stöhr, Sabine; Samudrala, Kiranmai; Raju, K A Kamesh; Mudholkar, Abhay

    2011-01-01

    Species rich benthic communities have been reported from some seamounts, predominantly from the Atlantic and Pacific Oceans, but the fauna and habitats on Indian Ocean seamounts are still poorly known. This study focuses on two seamounts, a submarine volcano (cratered seamount--CSM) and a non-volcano (SM2) in the Andaman Back-arc Basin (ABB), and the basin itself. The main purpose was to explore and generate regional biodiversity data from summit and flank (upper slope) of the Andaman seamounts for comparison with other seamounts worldwide. We also investigated how substratum types affect the megafaunal community structure along the ABB. Underwater video recordings from TeleVision guided Gripper (TVG) lowerings were used to describe the benthic community structure along the ABB and both seamounts. We found 13 varieties of substratum in the study area. The CSM has hard substratum, such as boulders and cobbles, whereas the SM2 was dominated by cobbles and fine sediment. The highest abundance of megabenthic communities was recorded on the flank of the CSM. Species richness and diversity were higher at the flank of the CSM than other are of ABB. Non-metric multi-dimensional scaling (nMDS) analysis of substratum types showed 50% similarity between the flanks of both seamounts, because both sites have a component of cobbles mixed with fine sediments in their substratum. Further, nMDS of faunal abundance revealed two groups, each restricted to one of the seamounts, suggesting faunal distinctness between them. The sessile fauna corals and poriferans showed a significant positive relation with cobbles and fine sediments substratum, while the mobile categories echinoderms and arthropods showed a significant positive relation with fine sediments only. PMID:21297959

  4. Megafaunal community structure of Andaman seamounts including the Back-arc Basin--a quantitative exploration from the Indian Ocean.

    PubMed

    Sautya, Sabyasachi; Ingole, Baban; Ray, Durbar; Stöhr, Sabine; Samudrala, Kiranmai; Raju, K A Kamesh; Mudholkar, Abhay

    2011-01-31

    Species rich benthic communities have been reported from some seamounts, predominantly from the Atlantic and Pacific Oceans, but the fauna and habitats on Indian Ocean seamounts are still poorly known. This study focuses on two seamounts, a submarine volcano (cratered seamount--CSM) and a non-volcano (SM2) in the Andaman Back-arc Basin (ABB), and the basin itself. The main purpose was to explore and generate regional biodiversity data from summit and flank (upper slope) of the Andaman seamounts for comparison with other seamounts worldwide. We also investigated how substratum types affect the megafaunal community structure along the ABB. Underwater video recordings from TeleVision guided Gripper (TVG) lowerings were used to describe the benthic community structure along the ABB and both seamounts. We found 13 varieties of substratum in the study area. The CSM has hard substratum, such as boulders and cobbles, whereas the SM2 was dominated by cobbles and fine sediment. The highest abundance of megabenthic communities was recorded on the flank of the CSM. Species richness and diversity were higher at the flank of the CSM than other are of ABB. Non-metric multi-dimensional scaling (nMDS) analysis of substratum types showed 50% similarity between the flanks of both seamounts, because both sites have a component of cobbles mixed with fine sediments in their substratum. Further, nMDS of faunal abundance revealed two groups, each restricted to one of the seamounts, suggesting faunal distinctness between them. The sessile fauna corals and poriferans showed a significant positive relation with cobbles and fine sediments substratum, while the mobile categories echinoderms and arthropods showed a significant positive relation with fine sediments only.

  5. Exploration for shallow compaction-induced gas accumulations in sandstones of the Fort Union Formation, Powder River Basin, Wyoming

    SciTech Connect

    Oldham, D.W.

    1997-01-01

    Commercial quantities of gas have been produced from shallow sandstone reservoirs of the Tongue River Member of the Fort Union Formation (Paleocene) in the Wyoming portion of the Powder River Basin. The two largest accumulations discovered to date, Oedekoven and Chan pools, were drilled on prospects which invoked differential compaction as a mechanism for gas entrapment and prospect delineation. Coal-sourced bacterial gas may have accumulated in localized structural highs early in the burial history of lenticular sand bodies and associated sediments. Structural relief is due to the compaction contrast between sand and stratigraphically equivalent fine-grained sediments. A shallow gas play targeting sandstones as potential reservoirs was initiated in the Recluse area in response as sources for bacterial gas, and the presence of lenticular sandstones that may have promoted the development of compaction structures early in the burial process, to which early-formed bacterial gas migrated. Prospects were ranked based on a number of geologic elements related to compaction-induced trap development. Drilling of the Oedekoven prospect, which possessed all prospect elements, led to the discovery and development of the Oedekoven Fort Union gas pool, which has produced nearly 2 BCF of gas from a depth of 340 ft. Production figures from the Oedekoven and Chan pools demonstrate the commercial gas potential of Fort Union sandstone reservoirs in the Powder River Basin. The shallow depths of the reservoirs, coupled with low drilling and completion costs, an abundance of subsurface control with which to delineate prospects, and an existing network of gas-gathering systems, make them attractive primary targets in shallow exploration efforts as well as secondary objectives in deeper drilling programs.

  6. Exploration

    USGS Publications Warehouse

    Wilburn, D.R.; Porter, K.E.

    1999-01-01

    This summary of international nonfuel mineral exploration activities for 1998 draws on available data from literature, industry and US Geological Survey (USGS) specialists. Data on exploration budgets by region and commodity are reported, significant mineral discoveries and exploration target areas are identified and government programs affecting the mineral exploration industry are discussed. Inferences and observations on mineral industry direction are drawn from these data and discussions.

  7. Identifying Oil Exploration Leads using Intergrated Remote Sensing and Seismic Data Analysis, Lake Sakakawea, Fort Berthold Indian Reservation, Willistion Basin

    SciTech Connect

    Scott R. Reeves; Randal L. Billingsley

    2004-02-26

    The Fort Berthold Indian Reservation, inhabited by the Arikara, Mandan and Hidatsa Tribes (now united to form the Three Affiliated Tribes) covers a total area of 1530 mi{sup 2} (980,000 acres). The Reservation is located approximately 15 miles east of the depocenter of the Williston basin, and to the southeast of a major structural feature and petroleum producing province, the Nesson anticline. Several published studies document the widespread existence of mature source rocks, favorable reservoir/caprock combinations, and production throughout the Reservation and surrounding areas indicating high potential for undiscovered oil and gas resources. This technical assessment was performed to better define the oil exploration opportunity, and stimulate exploration and development activities for the benefit of the Tribes. The need for this assessment is underscored by the fact that, despite its considerable potential, there is currently no meaningful production on the Reservation, and only 2% of it is currently leased. Of particular interest (and the focus of this study) is the area under the Lake Sakakawea (formed as result of the Garrison Dam). This 'reservoir taking' area, which has never been drilled, encompasses an area of 150,000 acres, and represents the largest contiguous acreage block under control of the Tribes. Furthermore, these lands are Tribal (non-allotted), hence leasing requirements are relatively simple. The opportunity for exploration success insofar as identifying potential leads under the lake is high. According to the Bureau of Land Management, there have been 591 tests for oil and gas on or immediately adjacent to the Reservation, resulting in a total of 392 producing wells and 179 plugged and abandoned wells, for a success ratio of 69%. Based on statistical probability alone, the opportunity for success is high.

  8. Geologic structures that affect Appalachian coal mines

    SciTech Connect

    Chase, F.E. )

    1993-01-01

    Hazardous geologic structures found in Appalachian coal mines have been responsible for numerous injuries and fatalities. In addition, these structures have been responsible for downtime and in some instances have even resulted in mine closures. For these reasons, the US Bureau of Mines has investigate the physical characteristics, occurrences, and support strategies to help anticipate and better control these structures. Structures that are addressed in this paper include slips, slickensides, clay veins, kettlebottoms, and sandstone channels.

  9. Mesozoic extension in the southern Appalachians

    SciTech Connect

    Heck, F.R. )

    1989-08-01

    Geophysical data from the southern Appalachians are generally interpreted in terms of Paleozoic collisional tectonics; the later effects of Mesozoic extension are often overlooked or downplayed. This paper reinterprets seismic reflection data from Georgia with the view that Mesozoic extension is responsible for most of the seismic reflection patterns one sees today. The interpretation suggests that geophysical data from a particular area reflect the most recent tectonic event rather than earlier and perhaps more geologically obvious events.

  10. Integrated exploration for low-temperature geothermal resources in the Honey Lake basin, California

    SciTech Connect

    Schimschal, U. )

    1991-02-01

    An integrated exploration study is presented to locate low-temperature geothermal reservoirs in the Honey Lake area of northern California. Regional studies to locate the geothermal resources included gravity, infrared, water-temperature, and water-quality analyses. Five anomalies were mapped from resistivity surveys. Additional study of three anomalies by temperature-gradient and seismic methods was undertaken to define structure and potential of the geothermal resource. The gravity data show a graben structure in the area. Seismic reflection data, indicate faults associated with surface-resistivity and temperature-gradient data. The data support the interpretation that the shallow reservoirs are replenished along the fault zones by deeply circulating heated meteoric waters.

  11. Integrated exploration for low-temperature geothermal resources in the Honey Lake Basin, California

    USGS Publications Warehouse

    Schimschal, U.

    1991-01-01

    An integrated exploration study is presented to locate low-temperature geothermal reservoirs in the Honey Lake area of northern California. Regional studies to locate the geothermal resources included gravity, infra-red, water-temperature, and water-quality analyses. Five anomalies were mapped from resistivity surveys. Additional study of three anomalies by temperature-gradient and seismic methods was undertaken to define structure and potential of the geothermal resource. The gravity data show a graben structure in the area. Seismic reflection data indicate faults associated with surface-resistivity and temperature-gradient data. The data support the interpretation that the shallow reservoirs are replenished along the fault zones by deeply circulating heated meteoric waters. -Author

  12. Perspectives on Healthy Eating Among Appalachian Residents

    PubMed Central

    Schoenberg, Nancy E.; Howell, Britteny M.; Swanson, Mark; Grosh, Christopher; Bardach, Shoshana

    2013-01-01

    Purpose Extensive attention has been focused on improving the dietary intake of Americans. Such focus is warranted due to increasing rates of overweight, obesity, and other dietary-related disease. To address suboptimal dietary intake requires an improved, contextualized understanding of the multiple and intersecting influences on healthy eating, particularly among those populations at greatest risk of and from poor diet, including rural residents. Methods During 8 focus groups (N=99) and 6 group key informant interviews (N=20), diverse Appalachian rural residents were queried about their perceptions of healthy eating, determinants of healthy food intake, and recommendations for improving the dietary intake of people in their communities. Participants included church members and other laypeople, public health officials, social service providers, health care professionals, and others. Findings Participants offered insights on healthy eating consistent with the categories of individual, interpersonal, community, physical, environmental and society-level influences described in the socioecological model. Although many participants identified gaps in dietary knowledge as a persistent problem, informants also identified extra-individual factors, including the influence of family, fellow church members, and schools, policy, advertising and media, and general societal trends, as challenges to healthy dietary intake. We highlight Appalachian residents’ recommendations for promoting healthier diets, including support groups, educational workshops, cooking classes, and community gardening. Conclusions We discuss the implications of these findings for programmatic development in the Appalachian context. PMID:23944277

  13. Deep Basalt Aquifers in Orcus Patera, Elysium Basin Mars: Perspectives for Exobiology Exploration

    NASA Technical Reports Server (NTRS)

    Grin, E. A.; Cabrol, N. A.

    1998-01-01

    Direct indicators of shorelines, spillways, and terraces allowed to determine the extent of the Elysium Paleolake between the contour-lines 1000 and 500 m below the Martian datum. The Elysium Paleolake is bordered north by Orcus Patera (14N/181W), which lies west of the Tartarus Montes and Tartarus Colles. The Orcus Patera displays an ellipse-shaped collapsed caldera of 360-km long and 100-km wide. Viking topographic data show that the bottom of the caldera is located at 2500 below the Martian datum, and surrounded by a steep-walled ram art which crest is located at about 0 m elevation. Considering the localization of Orcus Patera in the Elysium paleolake, its altimetry, and the magmatic origin of this caldera, we propose the existence of a paleolake in Orcus Patera generated (a) by juvenile water from magma during the Noachian period, and (b) by intermittent influx of the Elysium Basin from Hesperian to Amazonian. Results are encouraging to consider this site as a potential high-energy source environment for microbial communities. are circumscribed by a 50-km wide lava field mapped as Noachian material. The structure of Orcus Patera represents the record of material erupted from a magmatic reservoir. The caldera is enclosed by steep inner walls (25% measured from topographic data), values which could be in agreement with the presence of a deep magmatic reservoir, as suggested by the typology of Crumpler et.al. The depth of the caldera might be due to the collapse of the magma reservoir, and the release of gases accompanying the magma thermal evolution. Origins of water for the paleolake(s): The water that generated a paleolake in Orcus Patera may have come from two origins: (1) Juvenile water: Plescia and Crips estimated a magma H20 content by weight between 0.5% and 1.5% using for the first value a comparison with terrestrial basalt, and for the second values from a Martian meteorite. The amount of H20 can be estimated by the volume of erupted lava, and the lava

  14. Deep Basalt Aquifers in Orcus Patera, Elysium Basin Mars: Perspectives for Exobiology Exploration

    NASA Technical Reports Server (NTRS)

    Grin, E. A.; Cabrol, N. A.

    1998-01-01

    Direct indicators of shorelines, spillways, and terraces allowed to determine the extent of the Elysium Paleolake between the contour-lines 1000 and 500 m below the Martian datum. The Elysium Paleolake is bordered north by Orcus Patera (14N/181W), which lies west of the Tartarus Montes and Tartarus Colles. The Orcus Patera displays an ellipse-shaped collapsed caldera of 360-km long and 100-km wide. Viking topographic data show that the bottom of the caldera is located at 2500 below the Martian datum, and surrounded by a steep-walled ram art which crest is located at about 0 m elevation. Considering the localization of Orcus Patera in the Elysium paleolake, its altimetry, and the magmatic origin of this caldera, we propose the existence of a paleolake in Orcus Patera generated (a) by juvenile water from magma during the Noachian period, and (b) by intermittent influx of the Elysium Basin from Hesperian to Amazonian. Results are encouraging to consider this site as a potential high-energy source environment for microbial communities. are circumscribed by a 50-km wide lava field mapped as Noachian material. The structure of Orcus Patera represents the record of material erupted from a magmatic reservoir. The caldera is enclosed by steep inner walls (25% measured from topographic data), values which could be in agreement with the presence of a deep magmatic reservoir, as suggested by the typology of Crumpler et.al. The depth of the caldera might be due to the collapse of the magma reservoir, and the release of gases accompanying the magma thermal evolution. Origins of water for the paleolake(s): The water that generated a paleolake in Orcus Patera may have come from two origins: (1) Juvenile water: Plescia and Crips estimated a magma H20 content by weight between 0.5% and 1.5% using for the first value a comparison with terrestrial basalt, and for the second values from a Martian meteorite. The amount of H20 can be estimated by the volume of erupted lava, and the lava

  15. A Systems Approach to Identifying Exploration and Development Opportunities in the Illinois Basin: Digital Portifolio of Plays in Underexplored Lower Paleozoic Rocks

    SciTech Connect

    Beverly Seyler; David Harris; Brian Keith; Bryan Huff; Yaghoob Lasemi

    2008-06-30

    This study examined petroleum occurrence in Ordovician, Silurian and Devonian reservoirs in the Illinois Basin. Results from this project show that there is excellent potential for additional discovery of petroleum reservoirs in these formations. Numerous exploration targets and exploration strategies were identified that can be used to increase production from these underexplored strata. Some of the challenges to exploration of deeper strata include the lack of subsurface data, lack of understanding of regional facies changes, lack of understanding the role of diagenetic alteration in developing reservoir porosity and permeability, the shifting of structural closures with depth, overlooking potential producing horizons, and under utilization of 3D seismic techniques. This study has shown many areas are prospective for additional discoveries in lower Paleozoic strata in the Illinois Basin. This project implemented a systematic basin analysis approach that is expected to encourage exploration for petroleum in lower Paleozoic rocks of the Illinois Basin. The study has compiled and presented a broad base of information and knowledge needed by independent oil companies to pursue the development of exploration prospects in overlooked, deeper play horizons in the Illinois Basin. Available geologic data relevant for the exploration and development of petroleum reservoirs in the Illinois Basin was analyzed and assimilated into a coherent, easily accessible digital play portfolio. The primary focus of this project was on case studies of existing reservoirs in Devonian, Silurian, and Ordovician strata and the application of knowledge gained to future exploration and development in these underexplored strata of the Illinois Basin. In addition, a review of published reports and exploration in the New Albany Shale Group, a Devonian black shale source rock, in Illinois was completed due to the recent increased interest in Devonian black shales across the United States. The New

  16. Exploration

    USGS Publications Warehouse

    Wilburn, D.R.

    2005-01-01

    The worldwide budget for nonferrous, nonfuel mineral exploration was expected to increase by 58 percent in 2004 from the 2003 budget, according to Metals Economics Group (MEG) of Halifax, Nova Scotia. The increase comes two years after a five-year period of declining spending for mineral exploration (1998 to 2002). Figures suggest a subsequent 27 percent increase in budgeted expenditures from 2002 to 2003. For the second consecutive year, all regional exploration budget estimates were anticipated to increase.

  17. Anthropogenic Mercury Accumulation in Watersheds of the Northern Appalachian Mountains

    NASA Astrophysics Data System (ADS)

    Boyer, E. W.; Drohan, P. J.; Lawler, D.; Grimm, J.; Grant, C.; Eklof, K. J.; Bennett, J.; Naber, M. D.

    2014-12-01

    Atmospheric deposition of mercury (Hg) is a critical environmental stress that affects ecosystems and human health. Mercury emissions to the atmosphere from coal-fired power plants and other sources such as waste incineration can be deposited over large geographic areas to downwind landscapes in precipitation and in dry fallout. The northern Appalachian Mountains are downwind of major atmospheric mercury emissions sources. Some mercury reaches watersheds and streams, where it can accumulate in sediments and biota. Human exposure to mercury occurs primarily through fish consumption, and currently mercury fish eating advisories are in place for many of the streams and lakes in the region. Here, we explored mercury accumulation in forested landscapes - in air, soils, water, and biota. To quantify atmospheric mercury deposition, we measured both wet and dry mercury deposition at 10 forested locations, from which we present variation in mercury deposition and initial assessments of factors affecting the patterns. To quantify mercury accumulation in terrestrial environments, we measured soil mercury concentrations within and surrounding 12 vernal pools spanning various physiographic settings in the region. Given that vernal pools have large inputs of water via precipitation yet do not have any stream discharge outflow, they are likely spots within the forested landscape to accumulate pollutants that enter via wet atmospheric deposition. To quantify mercury accumulation in aquatic environments, we sampled mercury concentrations in streams draining 35 forested watersheds, spanning gradients of atmospheric deposition, climate and geology. Mercury concentrations were measured in stream water under base-flow conditions, in streambed sediments, aquatic mosses, and in fish tissues from brook trout. Results indicate that wet and dry atmospheric deposition is a primary source of mercury that is accumulating in watersheds of the Northern Appalachian Mountains.

  18. Vertical stacking of reservoirs in Silurian carbonates of Appalachian basin

    SciTech Connect

    Smosna, R.; Conrad, J.M.; Maxwell, T.C.

    1988-08-01

    The distribution of modern reefs and oolites is controlled to a large degree by sea-floor topography. Likewise, paleotopographic highs in the Silurian Lockport Dolomite and underlying Keefer Sandstone provided optimum sites for the deposition of boundstone and grainstone reservoir facies. The Keefer Sandstone in western West Virginia was deposited as a series of subtidal sand waves with a relief of a few meters. During initial Lockport sedimentation, the turbulence, water chemistry, and light intensity were most favorable in shallow water over the Keefer sand waves, encouraging growth of coral-stromatoporoid patch reefs. Skeletal banks in the upper Lockport of eastern Kentucky also were established over topographic highs of earlier Lockport mounds. In a similar fashion, the upper Lockport of West Virginia was deposited as oolitic shoals that formed atop exposed mud mounds in the middle member. A slight rise of sea level created the agitated subtidal environment above the now-submerged mud mounds, and oolite bars developed. The reef, skeletal-bank, and oolite facies of the Lockport, and the Keefer Sandstone, are all petroleum reservoirs. Carbonate reservoirs can be identified in the subsurface by thicks on isopach maps, by their clean gamma-ray signature, and by a relatively high log porosity. Based on these criteria, seven potential fairways have been mapped in Kentucky. Because the distribution of buildups was greatly influenced by that of their predecessors, five of the fairways contain vertically stacked reservoir facies. These are particularly attractive because they can be drilled as multistory targets.

  19. Apatite fission-track thermochronology of the Pennsylvania Appalachian Basin

    NASA Astrophysics Data System (ADS)

    Roden, Mary K.; Miller, Donald S.

    1989-09-01

    Thirty-four apatite fission-track apparent ages and twenty-four track length distributions for ash bed samples from the Valley and Ridge Province and Upper Devonian to Upper Pennsylvania sedimentary samples from the Allegheny Front and Allegheny Plateau of Pennsylvania suggest that these regions represent different thermal (uplift) regimes as well as different structural provinces. The Valley and Ridge Province Tioga and Kalkberg ash bed samples yield apatite fission-track apparent ages and track length distributions that indicate early post-Alleghanian (285-270 Ma) cooling and unroofing that began at ˜250 Ma. Assuming a geothermal gradient of 25°C km -1, a burial depth of at least 3.4 km can be estimated for all the Pennsylvania samples. At the Allegheny structural front and on the western Allegheny Plateau, the apatite fission-track apparent ages (<150 Ma) and track length measurements indicate a Late Jurassic-Early Cretaceous thermal event for these samples possibly resulting from a higher geothermal gradient coinciding with kimberlite intrusion at this time along the Greene-Potter Fault Zone. In northeast Pennsylvania on the Allegheny Plateau, the Upper Paleozoic sedimentary samples yield apatite fission-track apparent ages ≤180 Ma. Narrow track length distributions with long mean lengths (13-14 μm) and small standard deviations (1.3 μm) suggest rapid cooling from temperatures >110°C during the Middle Jurassic-Early Cretaceous for this part of Pennsylvania. This is consistent with the suggested uplift history of the Catskill Mountain region in adjacent New York State.

  20. Petroleum systems succeed play basis in Appalachian basin resource estimate

    USGS Publications Warehouse

    Milici, R.C.; Ryder, R.T.

    2004-01-01

    The US Geological Survey (USGS) periodically conducts subjective probabilistic assessments of the technically recoverable undiscovered hydrocarbon resources of the US and of the world. In addition, the USGS prepares forecasts of that portion of the technically recoverable resources that may be economic under specified conditions of supply, demand, and price. Depending on priorities, regional hydrocarbon assessments of the US are revised every 5 to 10 years. These assessments of undiscovered hydrocarbons supplement the data on hydrocarbon reserves that are reported annually by the US Department of Energy, Energy Information Administration. In between assessments, USGS assessment geologists conduct research and compile geologic and production data that may be used to improve future assessments. This new information commonly effects changes in the way the USGS defines "plays" or "assessment units" from assessment to assessment. Furthermore, USGS assessment methodology is in a constant state of evolution and changes to some degree from assessment to assessment.

  1. Tectonic geomorphology of the south-central Appalachians: The influence of Triassic extension

    SciTech Connect

    Webb, J.A. . Geology Dept.); Henika, W.S. . Division of Mineral Resources)

    1994-03-01

    During the final phase of the Alleghanian Orogeny, which ended probably in the mid-Permian, intense thrusting created a high mountain range with relief of up to 4.5 km and a width of 250--300 km. The drainage divide presumably lay within the Piedmont or Blue ridge Provinces, and probably ran subparallel to the present-day mid-Atlantic coastline. In the Middle and Late Triassic this mountain range was disrupted by the initial phases of rifting between the African and North American Plates. Many of the Alleghanian thrusts were reactivated as listric normal faults, creating a series of long, narrow asymmetric half grabens, and resulting in extensive delamination and thinning of the crust, particularly in the eastern Piedmont. South of the Salisbury Embayment the western limit of the Triassic basins steps consistently eastward, mirroring the offset of the ocean floor anomalies south of the Bermuda Fault Zone. The offset is also reflected by the easterly displacement of the present-day Appalachian drainage divide in southern virginia. This strongly suggests that the divide is largely inherited from the Triassic faulting episode. Rivers flowing westwards from the present-day Appalachians, including those like the New River crossing the Valley and Ridge Province, have retained more or less their pre-Triassic orientation, when they flowed down the western flanks of the Alleghanian mountains. The Triassic basins were separated by coast-parallel ranges with as much as 1 km of relief; these were largely eroded in the mid-Jurassic, so that by the Early Cretaceous the south-central Appalachians had more or less their present appearance. Subsequent erosion has probably resulted in westward retreat of the drainage divide.

  2. Appalachian Blue Ridge cover sequence ranges at least into the Ordovician

    NASA Astrophysics Data System (ADS)

    Tull, James F.; Ausich, William I.; Groszos, Mark S.; Thompson, Troy W.

    1993-03-01

    The first direct evidence that stratified rocks of the central core of the southern Appalachian Blue Ridge range in age into the Paleozoic comes from a pelmatozoan echinoderm column discovered within a unit directly above the Murphy Marble in North Carolina. Before this discovery most geologists had considered all stratified rocks of the Blue Ridge east of the frontal imbricate thrust blocks to be Late Proterozoic or Early Cambrian(?). The echinoderm fragment is in a lower amphibolite facies interbedded mica schist-impure marble zone that lies directly above the Murphy Marble. Rocks above the Murphy Marble are dominantly turbiditic metaclastic rocks with minor carbonate and metavolcanic rocks, interpreted as having formed within a successor basin unconformably above upper Precambrian rift facies and lower Paleozoic drift facies rocks of the Laurentian passive margin. An upper bound for the age of the successor basin in the Murphy belt has not been established; similar sequences in the Talladega belt to the southwest, and possibly the Foothills belt to the west, range at least into the Devonian. Most Appalachian tectonic models assert that during the Taconic orogeny a Middle Ordovician synorogenic clastic wedge, now located in the easternmost Tennessee foreland salient, was derived by erosion from the metamorphosed pre-Ordovician Blue Ridge basement and cover sequence to the east, which was uplifted as part of an advancing Taconic crystalline thrust wedge. The presence of Ordovician or younger rocks described here, which were deposited east of the proposed Taconic orogenic front, suggests the need to modify models for Taconic clastic wedge formation in the southern Appalachians. The results presented here also suggest that peak metamorphism in the region was post-Ordovician, and thus was probably not contemporaneous with the Taconic orogeny, as previously thought.

  3. Depositional history and petroleum potential of Middle and Upper Ordovician of Alabama Appalachians

    SciTech Connect

    Benson, J.D.; Mink, R.M.

    1983-09-01

    Middle and Upper Ordovician deposits occupy a significant position in the Paleozoic sequence in the southern Appalachians, since they represent a transition from passive margin carbonate to active margin clastic deposition. Middle Ordovician units show a transition from shallow-water deposits in the west to deeper water basinal deposits in the east. West of the Helena fault the Middle Ordovican is represented by peritidal to shallow subtidal lithologic characteristics of the Chickamauga Limestone. East of the Helena these shallow-water deposits are replaced by deeper water carbonates of the Lenoir and Little Oak Limestones and graptolitic shales of the Athens Formation. Red-green mudrocks of the Greensport Formation were deposited in shallow-shelf to tidal-flat environments and were in turn overlain by quartz arenites of the Colvin Mountain Sandstone, deposited as part of a shallow-barrier system. With continued uplift during the Late Ordovician, additional clastics prograded westward over the filled basin. Early Late Ordovician shallow-shelf to tidal-flat mudrocks of the Sequatchie Formation grade westward into shallow-water carbonates of the Inman and Leipers Formations. With continued input, Sequatchie clastics prograded westward and over-rode the westerly carbonates. A relative sea-level rise during the late Late Ordovican was accompanied by deposition of open-marine shelf, bioclastic limestones of the Sequatchie throughout much of the western Valley and Ridge. The petroleum potential of the Middle and Upper Ordovician sequence in the Alabama Appalachians appears to range from marginal to moderate. The existence of significant reservoirs in this area appears dependent upon the development of fracture porosity associated with Appalachian structures.

  4. 1974 Annual Report of the Appalachian Regional Commission.

    ERIC Educational Resources Information Center

    Kendrick, Elise F., Ed.; And Others

    Created via the Regional Development Act of 1965, the Appalachian Regional Commission documents its contributions to Appalachian socioeconomic development in this 1974 annual report. General areas of concern are identified as: (1) extension of public services to outlying areas; (2) improvement of public service quality and quantity; (3) promotion…

  5. Rates of Physical Activity among Appalachian Adolescents in Ohio

    ERIC Educational Resources Information Center

    Hortz, Brian; Stevens, Emily; Holden, Becky; Petosa, R. Lingyak

    2009-01-01

    Purpose: The purpose of this study was to describe the physical activity behavior of high school students living in the Appalachian region of Ohio. Methods: A cross-sectional sample of 1,024 subjects from 11 schools in Appalachian Ohio was drawn. Previously validated instruments were used to measure physical activity behavior over 7 days.…

  6. Overwhelmed in Cincinnati: Urban Appalachian Children and Youth. Draft.

    ERIC Educational Resources Information Center

    Borman, Kathryn M.

    The issues facing urban Appalachian children and their families in Cincinnati (Ohio) are addressed. Appalachians have the highest school dropout rate in Cincinnati proportionate to their numbers, with low access to jobs and generally poor access to, and use of, public services. Much of the information for this report comes from a survey of 246…

  7. 7 CFR 1005.2 - Appalachian marketing area.

    Code of Federal Regulations, 2010 CFR

    2010-01-01

    ... 7 Agriculture 9 2010-01-01 2009-01-01 true Appalachian marketing area. 1005.2 Section 1005.2 Agriculture Regulations of the Department of Agriculture (Continued) AGRICULTURAL MARKETING SERVICE (Marketing Agreements and Orders; Milk), DEPARTMENT OF AGRICULTURE MILK IN THE APPALACHIAN MARKETING AREA...

  8. 7 CFR 1005.2 - Appalachian marketing area.

    Code of Federal Regulations, 2011 CFR

    2011-01-01

    ... 7 Agriculture 9 2011-01-01 2011-01-01 false Appalachian marketing area. 1005.2 Section 1005.2 Agriculture Regulations of the Department of Agriculture (Continued) AGRICULTURAL MARKETING SERVICE (Marketing Agreements and Orders; Milk), DEPARTMENT OF AGRICULTURE MILK IN THE APPALACHIAN MARKETING AREA...

  9. 1970 Annual Report of the Appalachian Regional Commission.

    ERIC Educational Resources Information Center

    Appalachian Regional Commission, Washington, DC.

    During 1970, the Appalachian Regional Development Program completed its 5th year of operations. Authorized under the 1965 Appalachian Regional Development Act, the program tries to cooperatively promote Appalachia's future economic and social development through a phased series of public investments to improve education, health, transportation,…

  10. From Mountain to Metropolis: Appalachian Migrants in American Cities.

    ERIC Educational Resources Information Center

    Borman, Kathryn M., Ed.; Obermiller, Phillip J., Ed.

    This book consists of 14 essays that focus on the condition of urban Appalachians (former migrants to cities from Appalachia and their descendants). Chapters address issues of health, environment, education, and cultural identity in an urban Appalachian context, and are meant to be a resource for educators and health and human service…

  11. Drug Use among Urban Ethnic Youth: Appalachian and Other Comparisons.

    ERIC Educational Resources Information Center

    McCoy, Clyde B.; Watkins, Virginia McCoy

    1980-01-01

    Research findings show that, compared with Black, Polish, and other ethnic urban youth, urban Appalachian teenagers exhibit greater symptomatic behavior indicating severe difficulties in coping with urban environments. Particularly striking among these patterns, which hold for both females and males, is the heavy drug use among Appalachian youth.…

  12. 7 CFR 1005.2 - Appalachian marketing area.

    Code of Federal Regulations, 2012 CFR

    2012-01-01

    ... 7 Agriculture 9 2012-01-01 2012-01-01 false Appalachian marketing area. 1005.2 Section 1005.2 Agriculture Regulations of the Department of Agriculture (Continued) AGRICULTURAL MARKETING SERVICE (Marketing Agreements and Orders; Milk), DEPARTMENT OF AGRICULTURE MILK IN THE APPALACHIAN MARKETING AREA...

  13. 7 CFR 1005.2 - Appalachian marketing area.

    Code of Federal Regulations, 2013 CFR

    2013-01-01

    ... 7 Agriculture 9 2013-01-01 2013-01-01 false Appalachian marketing area. 1005.2 Section 1005.2 Agriculture Regulations of the Department of Agriculture (Continued) AGRICULTURAL MARKETING SERVICE (MARKETING AGREEMENTS AND ORDERS; MILK), DEPARTMENT OF AGRICULTURE MILK IN THE APPALACHIAN MARKETING AREA...

  14. 7 CFR 1005.2 - Appalachian marketing area.

    Code of Federal Regulations, 2014 CFR

    2014-01-01

    ... 7 Agriculture 9 2014-01-01 2013-01-01 true Appalachian marketing area. 1005.2 Section 1005.2 Agriculture Regulations of the Department of Agriculture (Continued) AGRICULTURAL MARKETING SERVICE (MARKETING AGREEMENTS AND ORDERS; MILK), DEPARTMENT OF AGRICULTURE MILK IN THE APPALACHIAN MARKETING AREA...

  15. The effect of Appalachian mountaintop mining on interior forest

    USGS Publications Warehouse

    Wickham, J.D.; Riitters, K.H.; Wade, T.G.; Coan, M.; Homer, C.

    2007-01-01

    Southern Appalachian forests are predominantly interior because they are spatially extensive with little disturbance imposed by other uses of the land. Appalachian mountaintop mining increased substantially during the 1990s, posing a threat to the interior character of the forest. We used spatial convolution to identify interior forest at multiple scales on circa 1992 and 2001 land-cover maps of the Southern Appalachians. Our analyses show that interior forest loss was 1.75-5.0 times greater than the direct forest loss attributable to mountaintop mining. Mountaintop mining in the southern Appalachians has reduced forest interior area more extensively than the reduction that would be expected based on changes in overall forest area alone. The loss of Southern Appalachian interior forest is of global significance because of the worldwide rarity of large expanses of temperate deciduous forest. ?? 2006 Springer Science+Business Media, Inc.

  16. Appalachian Studies for the High School Student with an Emphasis on Appalachian Literature.

    ERIC Educational Resources Information Center

    Hays, Jeanne Tarullo

    Designed to give Appalachian high school students an awareness of their own mountain culture, this guide begins with a section on values clarification and cultural awareness. Chapters II through V lay the groundwork and give reason and explanation to the works the students will examine in Chapter VI. These chapters deal with the geography,…

  17. Genesis of Mississippi Valley-Type deposits of the southernmost Appalachians: The black shale connection

    SciTech Connect

    Saunders, J.A.; Savrda, C.E. . Dept. of Geology)

    1993-03-01

    Mississippi Valley-Type (MVT) mineralization near the southern terminus of the Appalachians occurs in karstified Cambro-Ordovician Knox Group carbonates that lie beneath the Middle Ordovician Athens Shale. The Athens Shale is the organic-rich deep basinal facies of a foreland depocenter that formed at the onset of Taconic orogenesis and was subsequently deformed during multiple Appalachian orogenic events. Molybdenum, cobalt, and nickel concentrations in the Athens Shale are enriched relative to average shales and are comparable to typical black shales. MVT mineralization in northwest Georgia locally contains > 2,000 ppm Mo, > 500 ppm Ni, and > 30 ppm Co., concentrations which are anomalous compared to typical MVT deposits elsewhere. Given the stratigraphic proximity and geochemical similarities of the Athens Shale and the MVT mineralization, along with the presence of hydrothermal pyrite-quartz-calcite-barite-sphalerite veinlets in the Athens, the authors propose that the Athens Shale was the source of ore-forming solutions. Northwest-directed middle Paleozoic compressional deformation is interpreted to have focused Athens-derived fluids into the paleoaquifer at the top of the Knox Group. Although the significance of basin dewatering in the genesis of MVT deposits is generally accepted, direct hydrologic connection between a specific MVT deposit and source formation has not been recognized previously.

  18. INNOVATIVE METHODOLOGY FOR DETECTION OF FRACTURE-CONTROLLED SWEET SPOTS IN THE NORTHERN APPALACHIAN BASION

    SciTech Connect

    Rober Jacobi

    2006-05-31

    During this reporting period, Fortuna retrieved the first oriented horizontal core from the Trenton/Black River in the northern Appalachian Basin. The core came from central New York State, the ''hottest'' play in the Appalachian Basin. A complete well log suite was also collected in the horizontal hole, including an FMI log. After reassembling the core sections, and orienting the core, we analyzed the whole core before it was cut for full-diameter core analyses (e.g., permeability) and before the core was split, in order that we did not miss any features that may be lost during cutting. We recognized and mapped along the core 43 stylolites, 99 veins and several large partially filled vugs. Kinematic indicators suggest multiple phases of strike-slip motion. Master-abutting relationships at intersections (primarily determined from which feature ''cuts'' which other feature) show three stages of stylolite growth: sub horizontal, nearly vertical, and steeply dipping. These development stages reflect vertical loading, tectonic horizontal loading, and finally oblique loading. Hydrothermal dolomite veins cut and are cut by all three stages of the stylolites. A set of horizontal veins indicates vertical unloading. Analyses of the core will continue, as well as the well logs.

  19. Variations in carbonate shelf cycles in response to Appalachian tectonism

    SciTech Connect

    Algeo, T.J.

    1986-05-01

    Shelf facies strata of the Upper Mississippian Bangor Limestone in northwest Georgia and southeast Tennessee comprise asymmetric regressive cycles that are similar to shallowing-upward cycles described in many ancient and modern shallow marine carbonate sequences. Typical Bangor cycles consist of a lower 0.6-m transgressive hemicycle of poorly sorted intraclast-oolite grainstones, and an upper 15-m regressive hemicycle that grades vertically from open-marine fossil wackestone and packstone through barrier-bar oolite grainstone, to burrowed lagoonal wackestone and laminated fenestral tidal-flat mudstone and dolostone. Lateral variations in the number, thickness, and facies composition of cycles were controlled by the position of each Bangor section relative to the Mississippian shoreline and shelf margin, and by localized shelf downwarping in response to Appalachian foreland basin evolution. To the northeast, at Monteagle, Tennessee, evaporitic tidal flats flanked the low-lying Nashville dome. There, laminated fenestral mudstone and dolostone dominate a thin (58-m) Bangor section, with only one major marine transgression reaching this area. At Raccoon Mountain, Tennessee, in the midshelf area, syndepositional downwarping of the Raccoon Mountain trough controlled sedimentation and deposited a thick (120-m) Bangor section containing seven cycles of highly variable thickness and facies composition. To the southeast, at Pigeon Mountain, Georgia, the outer shelf was increasingly influenced by foreland basin sedimentation during the late Bangor. There, the lower part of a thin (52-m) Bangor section contains two normal regressive cycles, but abundant thin shale laminae and frequent facies shifts in the upper 15 m document increasing clastic influx and tectonic instability in source areas to the southeast.

  20. Exploration

    USGS Publications Warehouse

    Wilburn, D.R.

    2002-01-01

    Exploration budgets fell for a fourth successive year in 2001. These decreases reflected low mineral commodity prices, mineral-market investment reluctance, company failures and a continued trend of company mergers and takeovers.

  1. Estimating annual suspended-sediment loads in the northern and central Appalachian Coal region

    USGS Publications Warehouse

    Koltun, G.F.

    1985-01-01

    Multiple-regression equations were developed for estimating the annual suspended-sediment load, for a given year, from small to medium-sized basins in the northern and central parts of the Appalachian coal region. The regression analysis was performed with data for land use, basin characteristics, streamflow, rainfall, and suspended-sediment load for 15 sites in the region. Two variables, the maximum mean-daily discharge occurring within the year and the annual peak discharge, explained much of the variation in the annual suspended-sediment load. Separate equations were developed employing each of these discharge variables. Standard errors for both equations are relatively large, which suggests that future predictions will probably have a low level of precision. This level of precision, however, may be acceptable for certain purposes. It is therefore left to the user to asses whether the level of precision provided by these equations is acceptable for the intended application.

  2. Reservoir characterization of the Upper Jurassic geothermal target formations (Molasse Basin, Germany): role of thermofacies as exploration tool

    NASA Astrophysics Data System (ADS)

    Homuth, S.; Götz, A. E.; Sass, I.

    2015-06-01

    The Upper Jurassic carbonates of the southern German Molasse Basin are the target of numerous geothermal combined heat and power production projects since the year 2000. A production-orientated reservoir characterization is therefore of high economic interest. Outcrop analogue studies enable reservoir property prediction by determination and correlation of lithofacies-related thermo- and petrophysical parameters. A thermofacies classification of the carbonate formations serves to identify heterogeneities and production zones. The hydraulic conductivity is mainly controlled by tectonic structures and karstification, whilst the type and grade of karstification is facies related. The rock permeability has only a minor effect on the reservoir's sustainability. Physical parameters determined on oven-dried samples have to be corrected, applying reservoir transfer models to water-saturated reservoir conditions. To validate these calculated parameters, a Thermo-Triaxial-Cell simulating the temperature and pressure conditions of the reservoir is used and calorimetric and thermal conductivity measurements under elevated temperature conditions are performed. Additionally, core and cutting material from a 1600 m deep research drilling and a 4850 m (total vertical depth, measured depth: 6020 m) deep well is used to validate the reservoir property predictions. Under reservoir conditions a decrease in permeability of 2-3 magnitudes is observed due to the thermal expansion of the rock matrix. For tight carbonates the matrix permeability is temperature-controlled; the thermophysical matrix parameters are density-controlled. Density increases typically with depth and especially with higher dolomite content. Therefore, thermal conductivity increases; however the dominant factor temperature also decreases the thermal conductivity. Specific heat capacity typically increases with increasing depth and temperature. The lithofacies-related characterization and prediction of reservoir

  3. Combined interpretation of 3D seismic reflection attributes for geothermal exploration in the Polish Basin using self-organizing maps

    NASA Astrophysics Data System (ADS)

    Bauer, Klaus; Pussak, Marcin; Stiller, Manfred; Bujakowski, Wieslaw

    2014-05-01

    Self-organizing maps (SOM) are neural network techniques which can be used for the joint interpretation of multi-disciplinary data sets. In this investigation we apply SOM within a geothermal exploration project using 3D seismic reflection data. The study area is located in the central part of the Polish basin. Several sedimentary target horizons were identified at this location based on fluid flow rate measurements in the geothermal research well Kompina-2. The general objective is a seismic facies analysis and characterization of the major geothermal target reservoir. A 3D seismic reflection experiment with a sparse acquisition geometry was carried out around well Kompina-2. Conventional signal processing (amplitude corrections, filtering, spectral whitening, deconvolution, static corrections, muting) was followed by normal-moveout (NMO) stacking, and, alternatively, by common-reflection-surface (CRS) stacking. Different signal attributes were then derived from the stacked images including root-mean-square (RMS) amplitude, instantaneous frequency and coherency. Furthermore, spectral decomposition attributes were calculated based on the continuous wavelet transform. The resulting attribute maps along major target horizons appear noisy after the NMO stack and clearly structured after the CRS stack. Consequently, the following SOM-based multi-parameter signal attribute analysis was applied only to the CRS images. We applied our SOM work flow, which includes data preparation, unsupervised learning, segmentation of the trained SOM using image processing techniques, and final application of the learned knowledge. For the Lower Jurassic target horizon Ja1 we derived four different clusters with distinct seismic attribute signatures. As the most striking feature, a corridor parallel to a fault system was identified, which is characterized by decreased RMS amplitudes and low frequencies. In our interpretation we assume that this combination of signal properties can be

  4. Application of Advanced Exploration Technologies for the Development of Mancos Formation Oil Reservoirs, Jicarilla Apache Indian Nation, San Juan Basin, New Mexico

    SciTech Connect

    Reeves, Scott; Billingsley, Randy

    2002-09-09

    The objectives of this project are to: (1) develop an exploration rationale for the Mancos shale in the north-eastern San Juan basin; (2) assess the regional prospectivity of the Mancos in the northern Nation lands based on that rationale; (3) identify specific leads in the northern Nation as appropriate; (4) forecast pro-forma production, reserves and economics for any leads identified; and (5) package and disseminate the results to attract investment in Mancos development on the Nation lands.

  5. Reinterpretation of the Northern Terminus of the San Andreas Transform System: Implications for basin development and hydrocarbon exploration

    SciTech Connect

    Foland, S.S. ); Enzor, K.J. )

    1994-07-01

    The northern San Andreas transform system was studied to evaluate the tectonic history of offshore Point Arena basin, northern California. The Point Arena basin lies 250 km north of San Francisco and encompasses 8500 km[sup 2] on the outer continental shelf. It is a tertiary basin formed during Eocene subduction and overprinted by Pliocene-Pleistocene strike-slip motion of the San Andreas fault system. Interpretation of the data yields a new tectonic model for the northern San Andreas fault system and Point Arena basin. Previous models curved the fault system east parallel to the coast, intersecting faults exposed on Point Delgada, and then bending the fault sharply west to join the Mendocino triple junction. The new model projects the San Andreas fault system due northwest, straight into the offshore basin, as a series of parallel faults aligned with the onshore fault trace to directly intersect the triple junction. The new interpretation is supported by aeromagnetic data, which indicates the basin is divided by a major northwest-trending structural boundary and floored by two distinct basement types (Mesozoic Salinian granies and Jurassic Franciscan metasediments). The latest seismic data contain enough information to determine the genesis and orientation of the offshore fault system and associated folds. Basin modeling indicates hydrocarbon generation has occurred in the Miocene source beds. The model estimates the Point Arena basin contains multibillion barrel potential trapped in large antiforms associated with the through-going San Andreas system. Integration of all geotechnical data allowed reinterpretation of the tectonic history, and produced an enhanced understanding of Point Arena basin.

  6. Exploration for stratigraphic traps in a foreland basin using a sequence stratigraphic simulation: Examples from the Eocene/Oligocene of the Apure-Llanos basin, Venezuela

    SciTech Connect

    Reistroffer, J.; Levine, P.A.; Kendall, C.G. ); Finno, A. )

    1996-01-01

    Foreland basin depositional sequences provide a sensitive record of the interaction between tectonism, eustatic sea level fluctuations, and sedimentation rates. Interplay between these controlling factors creates sedimentary geometries which are unique to this tectonic setting and form excellent stratigraphic hydrocarbon traps. Incised valley fill deposits, [open quote]forced regression[close quote] deposits, and combination structure-stratigraphic traps are the predominant reservoir types. In an effort to extend our understanding of the development of these traps, the sequence stratigraphy of a regional seismic transact through the Apure-Llanos basin was simulated. From the Late Eocene through Oligocene, the Apure-Llanos basin was Characterized by multiple phases of compression and a southeast migrating depocenter. Sands of the Mirador and Carbonera formations, which onlap the Arauca Arch to the southeast, were shed from the Guyana craton and were Cannibalized from sediments along the deformation front to the northwest. These sands comprise the principal reservoirs in the study area. Shales of the Leon Formation, which act as a regional seal, were deposited during rapid flexural subsidence and eustatic sea level rise during the early Oligocene. The Arauca Arch acted as a focal mechanism for east and southeast migrating hydrocarbons. Simulation results predict an important stratigraphic pinchout of the Mirador Formation sands against the Arauca Arch, which correlates with the Arauca Reid in Colombia to the southwest. Also, modeling indicates that minimal Tertiary oil production In the La Victoria Field to the east is due to the lack of an adequate seal. Our results provide a conceptual model which predicts hydrocarbon reservoir and seal relationships in a foreland basin setting with limited data control.

  7. Exploration for stratigraphic traps in a foreland basin using a sequence stratigraphic simulation: Examples from the Eocene/Oligocene of the Apure-Llanos basin, Venezuela

    SciTech Connect

    Reistroffer, J.; Levine, P.A.; Kendall, C.G.; Finno, A.

    1996-12-31

    Foreland basin depositional sequences provide a sensitive record of the interaction between tectonism, eustatic sea level fluctuations, and sedimentation rates. Interplay between these controlling factors creates sedimentary geometries which are unique to this tectonic setting and form excellent stratigraphic hydrocarbon traps. Incised valley fill deposits, {open_quote}forced regression{close_quote} deposits, and combination structure-stratigraphic traps are the predominant reservoir types. In an effort to extend our understanding of the development of these traps, the sequence stratigraphy of a regional seismic transact through the Apure-Llanos basin was simulated. From the Late Eocene through Oligocene, the Apure-Llanos basin was Characterized by multiple phases of compression and a southeast migrating depocenter. Sands of the Mirador and Carbonera formations, which onlap the Arauca Arch to the southeast, were shed from the Guyana craton and were Cannibalized from sediments along the deformation front to the northwest. These sands comprise the principal reservoirs in the study area. Shales of the Leon Formation, which act as a regional seal, were deposited during rapid flexural subsidence and eustatic sea level rise during the early Oligocene. The Arauca Arch acted as a focal mechanism for east and southeast migrating hydrocarbons. Simulation results predict an important stratigraphic pinchout of the Mirador Formation sands against the Arauca Arch, which correlates with the Arauca Reid in Colombia to the southwest. Also, modeling indicates that minimal Tertiary oil production In the La Victoria Field to the east is due to the lack of an adequate seal. Our results provide a conceptual model which predicts hydrocarbon reservoir and seal relationships in a foreland basin setting with limited data control.

  8. Tectonic significance of Silurain magmatism in the Canadian Appalachians

    SciTech Connect

    Whalen, J.B.; Bevier, M.L. )

    1990-05-01

    New U-Pb ages for granites from the New Brunswick part of the Canadian Appalachians indicate that >90% of the undeformed felsic plutons are Silurian and not Devonian as previously thought. Silurian igneous and sedimentary assemblages were recently recognized throughout the Canadian Appalachians, although the petrogenetic types of magmas as well as the grades of metamorphism and deformation vary widely. Our data support proposed tectonic models that suggest relatively continuous subduction and orogenic activity in the Canadian Appalachians from Middle Ordovician to Middle Devonian time.

  9. Exploring Entrepreneurialism in Community Colleges in the Appalachian Region

    ERIC Educational Resources Information Center

    Hatfield, Sharon Lynn

    2010-01-01

    The combination of a weak economy with a corresponding decline in tax revenue has created deficits in state and local budgets which adversely affect the financial stability of community colleges. This leaves community colleges struggling to continue to provide education in support of their missions. To provide a source of alternative revenue,…

  10. The Aquitaine Basin: 60 years of gas exploration and production in the foreland of the Pyrenean fold and thrust belt

    SciTech Connect

    Le Vot, M.; Masset, J.M.; Biteau, J.J.

    1995-08-01

    Over the last 60 years, Exploration in the Aquitaine Basin has led to the discovery of about 13 TCF of gas associated with 100 MMBls of condensate. The first gas discovery was made on the St Marcet surface anticline in 1939. However the major step was accomplished in 1951 by the discovery of the Giant Lacq field (9 TCF of gas), which was followed in 1965 by the discovery of the Meillon Field (2,5 TCF). Production started in 1944 at St Marcel, in 1957 at Lacq and in 1967 at Meillon leading to a cumulative production of 10 TCF of gas as of December 1994. The fields are located in the immediate foreland of the Alpine Pyrenean Thrust Belt. The region shows as a result extreme structural complexity, which is also linked to the polyphased geological evolution of the area. Overprinted on the faulting pattern of the basement (Variscan and Hercynian orgenies), the area is characterized by a general E-W extension during the Jurassic and the Early Cretaceous, followed by a major submeridian compression from the Late Cretaceous to the Oligo-Miocene. In this context the traps for the fields consist in deep (3500 to 4500 m in average) faulted blocks derived from the Early to Mid Mesozoic extension, inverted at various degrees during the Late Cretaceous and Tertiary compressive events. In such a petroleum context, the challenge for the 90`s is to evaluate the remaining potential and to optimize the development of existing fields as well as to discover new fields especially within the unexplored zones along the leading edge of the Pyrenean Fold and Thrust Belt. Recent onshore 3D seismic (over 1500 km2 shot from 1987 to 1993) has proven to be efficient in defining good geometry for the fields and in delineating precisely the fractured zones of the reservoirs. It has as well allowed to develop a comprehensive understanding of the area and therefore a good evaluation of the unexplored zones within this very prolific region.

  11. 67. Smart view recreation area comfort station, reflecting Appalachian Architecture, ...

    Library of Congress Historic Buildings Survey, Historic Engineering Record, Historic Landscapes Survey

    67. Smart view recreation area comfort station, reflecting Appalachian Architecture, was completed by the summer of 1940 by era crews. View to the south-southeast. - Blue Ridge Parkway, Between Shenandoah National Park & Great Smoky Mountains, Asheville, Buncombe County, NC

  12. Young women's perspectives on cervical cancer prevention in Appalachian Kentucky.

    PubMed

    Head, Katharine J; Cohen, Elisia L

    2012-04-01

    Human papillomavirus (HPV) vaccination coupled with routine Papanicolaou (Pap) tests can prevent pervasive HPV infections causing cervical cancer. However, both HPV vaccination rates and Pap testing rates in Appalachian Kentucky are lower among all age groups than the rest of the United States. We recruited 19 young women residing in Appalachian Kentucky from university-based and rural clinical settings for group and individual interviews. After considering an integrated behavioral framework, we illustrate these women's perspectives by detailing five themes, including (a) experiential beliefs pose barriers to performing behaviors, (b) three vaccine doses complicate vaccination intention, (c) women have misunderstandings about HPV and the HPV vaccination function, (d) normative influences cue action (and inaction), and (e) specific environmental and contextual barriers exist to performing cervical cancer prevention behaviors in Appalachian Kentucky. These findings related to cervical cancer prevention in Appalachian Kentucky have implications for health-message design and clinical practice.

  13. On the Beam: The Appalachian Education Satellite Project

    ERIC Educational Resources Information Center

    Bramble, William J.; And Others

    1976-01-01

    Preliminary evaluation of a year's operation indicates the Appalachian Education Satellite Project is providing education courses to teachers at a reasonable cost and is proving that such an operation is feasible. (JC)

  14. Exploring the tecto-sedimentary history of the lower Kumano basin: insights from 3D seismic analysis

    NASA Astrophysics Data System (ADS)

    Ramirez, S. G.; Gulick, S. P.; Hayman, N. W.

    2013-12-01

    The Nankai accretionary margin is seismically active, representing a hazard for the people living along the southwestern Japanese shores. In an effort to better understand its behavior, 3D seismic and well data have been acquired in the area. We are using such data in order to address open research topics such as: the conditions for forearc basin initiation, the role of former slope basins and slope cover sediments in the formation of forearc basins and the role of changes in sedimentation as a major controlling factor in forearc basin evolution. New 3D maps of key surfaces that bound and lie within the lower Kumano basin help us illuminate these topics. The lower bounding surface, UC4, represents missing section between 5.6-3.8 Ma. Toward the SE UC4 is relatively undeformed, with some structures approximately parallel to the modern-day trench. In contrast, toward the NW UC4 is intensely deformed with two main synforms whose hinges are oriented 15 degrees to the modern-trench. The two synforms have similar wavelengths and amplitudes and define the thickest sediment accumulations in the lower Kumano basin. We hypothesize that UC4 had a protracted evolution with early synform (thrust-bound slope-basins?) followed by a change in the maximum strain/plate convergence direction. This change caused the structural trend observed to the SE. This interpretation is in agreement with previous independent estimations of block rotation based on paleomagnetic analysis of samples from core recovered in the area. The upper bounding surface of the lower Kumano basin, UC2, underlies 1.6 Ma and younger sediments. Its morphology resembles a much smoother and less deformed version of UC4. It is slightly tilted landward. Seaward, it pinches out against UC4. Between the two bounding surfaces we recognized a major unconformity that we called UC3a and that we were able to track through most of the studied part of the seismic volume. Morphologically, UC3a is very similar to UC2. We interpret

  15. "Can We Send Some of the Money Back Home to Our Families?" Tensions of Transition in an Early Intervention Program for Rural Appalachian Students.

    ERIC Educational Resources Information Center

    Carter, Carolyn S.; Robinson, Ruby

    This paper explores issues surrounding the interplay of college preparation, financial assistance, cultural norms, and transition to college for Appalachian first-generation college students from low-income rural families. The Robinson Scholars Program aims to significantly improve the college-going rate in 29 counties in eastern Kentucky. The…

  16. Exploring the influence of precipitation extremes and human water use on total water storage (TWS) changes in the Ganges-Brahmaputra-Meghna River Basin

    NASA Astrophysics Data System (ADS)

    Khandu; Forootan, Ehsan; Schumacher, Maike; Awange, Joseph L.; Müller Schmied, Hannes

    2016-03-01

    Climate extremes such as droughts and intense rainfall events are expected to strongly influence global/regional water resources in addition to the growing demands for freshwater. This study examines the impacts of precipitation extremes and human water usage on total water storage (TWS) over the Ganges-Brahmaputra-Meghna (GBM) River Basin in South Asia. Monthly TWS changes derived from the Gravity Recovery And Climate Experiment (GRACE) (2002-2014) and soil moisture from three reanalyses (1979-2014) are used to estimate new extreme indices. These indices are applied in conjunction with standardized precipitation indices (SPI) to explore the impacts of precipitation extremes on TWS in the region. The results indicate that although long-term precipitation do not indicate any significant trends over the two subbasins (Ganges and Brahmaputra-Meghna), there is significant decline in rainfall (9.0 ± 4.0 mm/decade) over the Brahmaputra-Meghna River Basin from 1998 to 2014. Both river basins exhibit a rapid decline of TWS from 2002 to 2014 (Ganges: 12.2 ± 3.4 km3/yr and Brahmaputra-Meghna: 9.1 ± 2.7 km3/yr). While the Ganges River Basin has been regaining TWS (5.4 ± 2.2 km3/yr) from 2010 onward, the Brahmaputra-Meghna River Basin exhibits a further decline (13.0 ± 3.2 km3/yr) in TWS from 2011 onward. The impact of human water consumption on TWS appears to be considerably higher in Ganges compared to Brahmaputra-Meghna, where it is mainly concentrated over Bangladesh. The interannual water storage dynamics are found to be strongly associated with meteorological forcing data such as precipitation. In particular, extreme drought conditions, such as those of 2006 and 2009, had profound negative impacts on the TWS, where groundwater resources are already being unsustainably exploited.

  17. Devonian shale gas resource assessment, Illinois basin

    SciTech Connect

    Cluff, R.M.; Cluff, S.G.; Murphy, C.M.

    1996-12-31

    In 1980 the National Petroleum Council published a resource appraisal for Devonian shales in the Appalachian, Michigan, and Illinois basins. Their Illinois basin estimate of 86 TCFG in-place has been widely cited but never verified nor revised. The NPC estimate was based on extremely limited canister off-gas data, used a highly simplified volumetric computation, and is not useful for targeting specific areas for gas exploration. In 1994 we collected, digitized, and normalized 187 representative gamma ray-bulk density logs through the New Albany across the entire basin. Formulas were derived from core analyses and methane adsorption isotherms to estimate total organic carbon (r{sup 2}=0.95) and gas content (r{sup 2}=0.79-0.91) from shale bulk density. Total gas in place was then calculated foot-by-foot through each well, assuming normal hydrostatic pressures and assuming the shale is gas saturated at reservoir conditions. The values thus determined are similar to peak gas contents determined by canister off-gassing of fresh cores but are substantially greater than average off-gas values. Greatest error in the methodology is at low reservoir pressures (or at shallow depths), however, the shale is generally thinner in these areas so the impact on the total resource estimate is small. The total New Albany gas in place was determined by integration to be 323 TCFG. Of this, 210 TCF (67%) is in the upper black Grassy Creek Shale, 72 TCF (23%) in the middle black and gray Selmier Shale, and 31 TCF (10%) in the basal black Blocher Shale. Water production concerns suggest that only the Grassy Creek Shale is likely to be commercially exploitable.

  18. Devonian shale gas resource assessment, Illinois basin

    SciTech Connect

    Cluff, R.M.; Cluff, S.G.; Murphy, C.M. )

    1996-01-01

    In 1980 the National Petroleum Council published a resource appraisal for Devonian shales in the Appalachian, Michigan, and Illinois basins. Their Illinois basin estimate of 86 TCFG in-place has been widely cited but never verified nor revised. The NPC estimate was based on extremely limited canister off-gas data, used a highly simplified volumetric computation, and is not useful for targeting specific areas for gas exploration. In 1994 we collected, digitized, and normalized 187 representative gamma ray-bulk density logs through the New Albany across the entire basin. Formulas were derived from core analyses and methane adsorption isotherms to estimate total organic carbon (r[sup 2]=0.95) and gas content (r[sup 2]=0.79-0.91) from shale bulk density. Total gas in place was then calculated foot-by-foot through each well, assuming normal hydrostatic pressures and assuming the shale is gas saturated at reservoir conditions. The values thus determined are similar to peak gas contents determined by canister off-gassing of fresh cores but are substantially greater than average off-gas values. Greatest error in the methodology is at low reservoir pressures (or at shallow depths), however, the shale is generally thinner in these areas so the impact on the total resource estimate is small. The total New Albany gas in place was determined by integration to be 323 TCFG. Of this, 210 TCF (67%) is in the upper black Grassy Creek Shale, 72 TCF (23%) in the middle black and gray Selmier Shale, and 31 TCF (10%) in the basal black Blocher Shale. Water production concerns suggest that only the Grassy Creek Shale is likely to be commercially exploitable.

  19. Meeting the special needs of Appalachian alcoholics.

    PubMed

    Beltrame, T F

    1978-12-01

    The Appalachian Regional Comprehensive Alcoholism Program in Beckley, West Virginia, was established in 1972 to meet the needs of a four-county catchment area. In designing the program, planners took into account the special cultural and economic characteristics of the population to be served--individualism, isolation, religiosity, conservatism, distrust of newcomers, and economic deprivation--and set up a program they believe respects local norms. For instance, the program has been staffed mainly by local professionals. Individual therapy, family therapy, and crisis intervention are used much more frequently than group psychotherapy, and clients have a strong voice in treatment decisions. Local ministerial associations are involved whenever possible, and outreach efforts include home visits as well as the use of the media to disseminate information.

  20. Adjuvant therapy use among Appalachian breast cancer survivors.

    PubMed

    Tan, Xi; Marshall, Vincent D; Anderson, Roger T; Donohoe, Joseph; Camacho, Fabian; Balkrishnan, Rajesh

    2015-07-01

    There is a paucity of literature systemically examining the effects of access to cancer care resources on adjuvant endocrine therapy (AET) use behaviors, especially in underserved regions such as the Appalachian region in the United States, where gaps in healthcare access are well documented. The objectives of this study were to explore AET adherence and persistence in Appalachia, delineate the effects of access to care cancer on adherence/persistence, and evaluate the influences of adherence and persistence on overall survival.A retrospective cohort study from 2006 to 2008 was conducted among female breast cancer survivors living in the Appalachian counties of 4 states (PA, OH, KY, and NC). We linked cancer registries to Medicare claims data and included patients with invasive, nonmetastatic, hormone-receptor-positive breast cancer who received guideline-recommended AET. Medication adherence was defined as corresponding to a Medication Possession Ratio (MPR) ≥0.8 and logistic regression was utilized to assess predictors of adherence. Medication nonpersistence was defined as the discontinuation of drugs after exceeding a 60-day medication gap, and multivariate adjusted estimates of nonpersistence were obtained using the Cox proportional hazards (PH) model.About 31% of the total 428 patients were not adherent to AET, and 30% were not persistent over an average follow-up period of 421 days. Tamoxifen, relative to aromatase inhibitors, was associated with higher odds of adherence (odds ratio = 2.82, P < 0.001) and a lower risk of nonpersistence (hazard ratio = 0.40, P < 0.001). Drug-related side effects like pain may be an important factor leading to nonadherence and early discontinuation. In addition, aromatase inhibitor (AI) adherence and persistence were significantly influenced by out-of-pocket drug costs, dual eligibility status, and coverage gaps. Nonadherence to and nonpersistence with AET were associated with higher risks of all-cause mortality.Our findings

  1. Provenance characterization of Appalachian clastic wedges from sandstone petrography and clast compositions

    SciTech Connect

    Eriksson, K.A. . Dept. of Geological Science); Simpson, E.L. . Dept. of Physical Science); Krogstad, E.J. . Dept. of Geology); McLennan, S.M. . Dept. of Earth and Space Science); Norman, M. )

    1994-03-01

    Sandstones in the Taconic, Acadian and Alleghanian clastic wedges in the Appalachian Orogenic Belt provide evidence for changing provenances during the late Ordovician through pennsylvanian, Neoproterozoic-Early Cambrian, synrift sandstones are predominantly feldspathic arenites, whereas quartz arenites typify sandstones in the Cambrian passive-margin prism. In contrast, sandstones in the overlying foreland-basin clastic wedges typically are lithic arenites and occupy the quartzose to lithic recycled fields on QmFLt diagrams. Mid-Ordovician lithic arenites (Knobs, Bays Fms.) are dominated by a variety of sedimentary rock fragments including feldspathic and quartz arenites, limestone, dolomite and chert. Conglomerates in the Bays Formation similarly are dominated by recycled sedimentary clasts; gneiss clasts are only rarely observed. Above a regional unconformity in the middle Tuscarora formation, a succession of quartz arenites (upper Tuscarora, Rose Hill and Eagle Rock Fms.) developed in response to prolonged reworking. Overlying lithic arenites (Middle Devonian-Pennsylvanian) contain a variety of metamorphic rock fragments including quartz-mica schist, strained and polycrystalline quartz, and detrital mica. Sandstone petrography and clast compositions thus indicate that the Taconic orogeny involved uplift of the older passive-margin prism in a fold-and-thrust belt or accretionary prism. Coarse-grained sedimentary rocks provide no evidence of an arc to the east. Mature Silurian sandstones record an inter-orogenic, quiescent phase of the Appalachian Orogeny.

  2. Role of debris flows in long-term landscape denudation in the central Appalachians of Virginia

    USGS Publications Warehouse

    Eaton, L.S.; Morgan, B.A.; Kochel, R.C.; Howard, A.D.

    2003-01-01

    Four major storms that triggered debris flows in the Virginia-West Virginia Appalachians provide new insights into the role of high-magnitude, low-frequency floods in long-term denudation and landscape evolution in mountainous terrain. Storm denudation in the Blue Ridge Mountain drainage basins in approximately an order of magnitude greater compared to basins located in the mountains of the Valley and Ridge province. This difference is probably the result of higher storm rainfall from the Blue Ridge storms. Radiocarbon dating of debris-flow deposits in the Blue Ridge indicates a debris-flow return interval of not more than 2-4 k.y, in mountainous river basins. This finding, combined with measurements of basin denudation, suggests that approximately half of the long-term denudation from mechanical load occurs episodically by debris-flow processes. Although floods of moderate magnitude are largely responsible for mobilizing sediment in low-gradient streams, our data suggest that high-magnitude, low-frequency events are the most significant component in delivering coarse-grained regolith from mountainous hollows and channels to the lowland floodplains.

  3. Seismic expression of depositional systems tracts and application to hydrocarbon exploration in Bredasdorp basin, offshore South Africa

    SciTech Connect

    Beamish, G.W.J.

    1989-03-01

    Postrift Cretaceous sequences of Bredasdorp basin, offshore South Africa, were rigorously analyzed using the unified application of the latest seismic-stratigraphic, sequence-stratigraphic, and depositional systems concepts. Using 101 seismic profiles totaling 5600 km, the authors identified ten cyclic depositional sequences bounded by nine type 1 and two type 2 unconformities. Component depositional systems tracts exhibit a distinct seismic expression and can be delineated using truncation and lap-out relationships. Lowstand systems tracts developed on type 1 unconformities, which resulted from relative sea level fall below the shelf edge. In a terrigenous clastic basin such as Bredasdorp, these tracts are interpreted as being composed of basin-floor turbidite fans, channels, and/or sheets. These features formed contemporaneously with the erosion of incised valleys and submarine canyons, followed by channelized slope fans and deltaic/coastal lowstand wedges that prograded during a relative sea level rise. Subsequent flooding of the shelf as relative sea level rise accelerated resulted in poorly defined transgressive systems tracts. With the relative sea level at a highstand, extensively developed deltaic/coastal systems prograded basinward exhibiting well-defined clinoforms. The major hydrocarbon plays in the lowstand tracts occur as mounded basin-floor turbidite fans, channel fills, and draped sheets and are found in the updip pinch-out of deltaic/coastal sandstones.

  4. Exploring the Geomorphology of the Amazon's Planalto and Understanding the Origin of the Modern Amazon Basin with Imaging Radar:

    NASA Astrophysics Data System (ADS)

    Islam, R.; McDonald, K. C.; Azarderakhsh, M.; Campbell, K.; Cracraft, J.; Carnaval, A. C.

    2015-12-01

    The Amazon basin is a biodiversity biome and plays a significant role into shaping the earth's climate, ocean and atmospheric gases. Understanding the history of the formation of the basin is essential to our understanding of the region's biodiversity loss and response to climate change. Ancient River channels in lowland Amazonia exhibit right angle branching structures as well as intricately intertwined channels. Past research has attributed these characteristic as a result of subsurface faults but makes it difficult to validate this augment due to dense vegetation and sedimentation. We seek to employ remote sensing techniques for examining geomorphological features and the relationship to evolutionary processes that shaped biodiversity in the modern Amazon River Basin. We utilize UAVSAR imagery gathered from the NASA/JPL airborne imaging radar over the Planalto, in the Madre de Dios region of Southeastern Peru in an assessment of the underlying geomorphology, its relationship to the current distribution of vegetation, and geologic processes through deep time. In the late Neogene, the Amazonian lowlands comprised either a series of independent basins or a single sedimentary basin. The Amazonian Planalto is variously described as either erosional surface or a surface of deposition. We employ UAVSAR data collection to assess (1) the utility of these radar data for use in identifying associated geomorphologic features, and (2) UAVSAR's utility in aiding interpretation of ALOS PALSAR and STRM datasets to support a basin-wide characterization. We derive maps of river networks using a canny based edge detection method applied on the UAVSAR backscatter images. We develop an algorithm, which separates the river networks into various catchments based on connected component and then calculates angles at each branch point. We then assess distribution of right angle branching structure throughout the entire region. The results of the analysis will have a major impact on

  5. Synergetic study of Silurian-Niagaran pinnacle reef belt around the Michigan Basin for exploration and production of oil and gas. Volumes 1 and 2

    SciTech Connect

    Aminian, K.

    1982-01-01

    The Silurian-Niagaran pinnacle reef occur on a belt which encircles the entire Michigan Basin including areas presently covered by the Great Lakes Huron and Michigan. Two different structural settings existed in the Michigan Basin during the Silurian Period. This resulted in formation of pinnacle reefs with somewhat different characteristics in the northern and southern parts of the basin. The pinnacles of the northern trend occur at depths of 4000 to 7000 ft, are up to 700 ft thick, and average about 100 acres in area. The southern pinnacles occur at depths of 2000 to 3000 ft, are shorter, about 300 ft, and attain larger areas. The majority of the hydrocarbon reserves of the northern trend are concentrated in pinnacles which occur on a band 3 to 4 miles wide inside the middle of the trend. There exists a regional partitioning of oil and gas in the northern pinnacle reefs which can be best explained by Gussaw Theory of migration and differential entrapment. A probabilistic model for exploration in play was found applicable in mature areas of the northern trend. The results were extended to other parts of the northern trend based on similar reef density and size distribution. In the southern trend where the reef density and size distribution is entirely different, the model was tested against limited data and results of future exploration were predicted. The effectiveness of exploration on the reef belt, based on seismic surveys, is 8 to 10 times better than random drilling. The reserves of the reef belt is in excess of 7 bbl of oil and 15 trillion ft/sup 3/ of natural gas originally in place. The oil primary and secondary recovery factors are 20 and 30%, respectively.

  6. The potential for coalbed gas exploration and production in the Greater Green River Basin, southwest Wyoming and northwest Colorado

    SciTech Connect

    Tyler, R.; Kaiser, W.R.; Scott, A.R.; Hamilton, D.S.

    1997-01-01

    Coalbed gas is an important source of natural gas in the United States. In 1993, approximately 740 BCF of coalbed gas was produced in the United States, or about 4.2% of the nation`s total gas production. Nearly 96% of this coalbed gas is produced from just two basins, the San Juan (615.7 BCF; gas in place 84 TCF) and Black Warrior (105 BCF; gas in place 20 TCF), and current production represents only a fraction of the nation`s estimated 675 TCF of in-place coalbed gas. Coal beds in the Greater Green River Basin in southwest Wyoming and northwest Colorado hold almost half of the gas in place (314 TCF) and are an important source of gas for low-permeability Almond sandstones. Because total gas in place in the Greater Green River Basin is reported to exceed 3,000 TCF (Law et al., 1989), the basin may substantially increase the domestic gas resource base. Therefore, through integrated geologic and hydrologic studies, the coalbed gas potential of the basin was assessed where tectonic, structural, and depositional setting, coal distribution and rank, gas content, coal permeability, and ground-water flow are critical controls on coalbed gas producibility. Synergism between these geologic and hydrologic controls determines gas productivity. High productivity is governed by (1) thick, laterally continuous coals of high thermal maturity, (2) basinward flow of ground water through fractured and permeable coals, down the coal rank gradient toward no-flow boundaries oriented perpendicular to the regional flow direction, and (3) conventional trapping of gas along those boundaries to provide additional sources of gas beyond that sorbed on the coal surface.

  7. A record of Appalachian denudation in postrift Mesozoic and Cenozoic sedimentary deposits of the U.S. Middle Atlantic continental margin

    USGS Publications Warehouse

    Poag, C.W.; Sevon, W.D.

    1989-01-01

    The complex interplay between source-terrain uplift, basin subsidence, paleoclimatic shifts, and sea-level change, left an extensive sedimentary record in the contiguous offshore basins of the U.S. middle Atlantic margin (Salisbury Embayment, Baltimore Canyon Trough, and Hatteras Basin). Isopach maps of 23 postrift (Lower Jurassic to Quaternary) a allostratigraphic units, coupled with a revised stratigraphic framework, reveal that tectonism, by regulating sediment supply (accumulation rate), dominated the interplay of forcing mechanisms. Tectonic pulses are evidenced by abruptly accelerated sediment accumulation, marked latitudinal shifts in the location of depocenters, and regional changes in lithofacies. Relatively rapid tectonic subsidence during the Early and Middle Jurassic history of the basins may have enhanced sediment accumulation rates. Beginning in the Late Jurassic, however, subsidence rates decreased significantly, though occasional short pulses of subsidence may have effected relative sea-level rises. Sea-level change heavily influenced the distribution and redistribution of sediments one they reached the basins, and paleoclimate regulated the relative abundance of carbonates and evaporites in the basins. We conclude that source terrains of the central Appalachian Highlands were tectonically uplifted, intensely weathered, and rapidly eroded three times since the Late Triassic: (1) Early to Middle Jurassic (Aalenian to Callovian); (2) mid-Early Cretaceous (Barremian); and (3) Late Cenozoic (Middle Miocene). Intervals of tectonic quiescence following these three tectonic pulses provided conditions suitable for the formation of regional erosion surfaces, geomorphic features commonly reported to characterize the central Appalachian Highlands. This series of three, irregularly spaced, tectonic/quiescent cycles does not, however, match the traditional four-cycle concept of post-Triassic Appalachian "peneplanation". ?? 1989.

  8. Recovery act. Characterizing structural controls of EGS-candidate and conventional geothermal reservoirs in the Great Basin. Developing successful exploration strategies in extended terranes

    SciTech Connect

    Faulds, James

    2015-06-25

    We conducted a comprehensive analysis of the structural controls of geothermal systems within the Great Basin and adjacent regions. Our main objectives were to: 1) Produce a catalogue of favorable structural environments and models for geothermal systems. 2) Improve site-specific targeting of geothermal resources through detailed studies of representative sites, which included innovative techniques of slip tendency analysis of faults and 3D modeling. 3) Compare and contrast the structural controls and models in different tectonic settings. 4) Synthesize data and develop methodologies for enhancement of exploration strategies for conventional and EGS systems, reduction in the risk of drilling non-productive wells, and selecting the best EGS sites.

  9. Appalachian Piedmont landscapes from the Permian to the Holocene

    USGS Publications Warehouse

    Cleaves, E.T.

    1989-01-01

    Between the Potomac and Susquehanna Rivers and from the Blue Ridge to the Fall Zone, landscapes of the Piedmont are illustrated for times in the Holocene, Late Wisconsin, Early Miocene, Early Cretaceous, Late Triassic, and Permian. Landscape evolution took place in tectonic settings marked by major plate collisions (Permian), arching and rifting (Late Triassic) and development of the Atlantic passive margin by sea floor spreading (Early Cretaceous). Erosion proceeded concurrently with tectonic uplift and continued after cessation of major tectonic activity. Atlantic Outer Continental Shelf sediments record three major erosional periods: (1) Late Triassic-Early Jurassic; (2) Late Jurassic-Early Cretaceous; and (3) Middle Miocene-Holocene. The Middle Miocene-Holocene pulse is related to neotectonic activity and major climatic fluctuations. In the Piedmont upland the Holocene landscape is interpreted as an upland surface of low relief undergoing dissection. Major rivers and streams are incised into a landscape on which the landforms show a delicate adjustment to rock lithologies. The Fall Zone has apparently evolved from a combination of warping, faulting, and differential erosion since Late Miocene. The periglacial environment of the Late Wisconsin (and earlier glacial epochs) resulted in increased physical erosion and reduced chemical weathering. Even with lowered saprolitization rates, geochemical modeling suggests that 80 m or more of saprolite may have formed since Late Miocene. This volume of saprolite suggests major erosion of upland surfaces and seemingly contradicts available field evidence. Greatly subdued relief characterized the Early Miocene time, near the end of a prolonged interval of tropical morphogenesis. The ancestral Susquehanna and Potomac Rivers occupied approximately their present locations. In Early Cretaceous time local relief may have been as much as 900 m, and a major axial river draining both the Piedmont and Appalachians flowed southeast

  10. Benthic communities in the deep Mediterranean Sea: exploring microbial and meiofaunal patterns in slope and basin ecosystems

    NASA Astrophysics Data System (ADS)

    Sevastou, K.; Lampadariou, N.; Polymenakou, P. N.; Tselepides, A.

    2013-07-01

    The long-held perception of the deep sea consisting of monotonous slopes and uniform oceanic basins has over the decades given way to the idea of a complex system with wide habitat heterogeneity. Under the prism of a highly diverse environment, a large dataset was used to describe and compare spatial patterns of the dominant small-size components of deep-sea benthos, metazoan meiofauna and microbes, from Mediterranean basins and slopes. A grid of 73 stations sampled at five geographical areas along the central-eastern Mediterranean Basin (central Mediterranean, northern Aegean Sea, Cretan Sea, Libyan Sea, eastern Levantine) spanning over 4 km in depth revealed a high diversity, irrespective of the benthic group or level of taxonomic analysis. A common decreasing bathymetric trend was detected for meiobenthic abundance, major taxa diversity and nematode genera richness, but no differences were found between the two habitats (basin vs slope). In contrast, microbial richness is significantly higher at the basin ecosystem and tends to increase with depth. Multivariate analyses (β- and δ-diversity and ordination analysis) complemented these results and underlined the high within-habitat variability of benthic communities. Meiofaunal communities in particular were found to change gradually and vary more towards the abyss. On the other hand, microbial communities were highly variable, even among samples of the same area, habitat and bathymetry. A significant proportion of the variation of benthic communities and their descriptors was explained by depth and proxies of food availability (sedimentary pigments and organic content), but the combination of predictor variables and the strength of the relationship varied depending on the data set used (based on type of habitat, benthic component, taxonomic level). This, along with the observed high within-habitat variability suggests that other factors, which tend to vary at local scale (hydrodynamics, substrate structure

  11. Ma'adim Vallis Estuarine Delta in Elysium Basin and Its Relevance as a Landing Site for Exobiology Exploration on Mars

    NASA Technical Reports Server (NTRS)

    Grin, E. A.; Cabrol, N. A.

    1998-01-01

    inflowing fluvial water. This results in the rising of the channel base-level, thus in the increase of the length of the longitudinal graded-profile. The sediment deposit facies of the zone A shows a generally smooth surface. The longitudinal deposit is bordered by alluvial terraces that reflect the variations of the channel level. The waning of the Elysium Basin caused the erosion of the Basin estuarine zone by small channels, this episode being characterized by dissected tear-drop shaped mesa-like morphologies in the delta. Our estuarine delta model predicts a lithostratigraphic depositional sequence associated with the water submergence and the transgression of Elysium Basin. The thickness of the estuarine sediment corresponds to the Elysium Basin levels changes relatively to the bed floor of the estuary, The depositional sequence of Ma'adim Vallis are described: (1) a pro-current filled region (A), where fluvial are longitudinally accumulated by the inflowing water, (2) inverse current from Elysium Basin (B), where fluvial and lacustrine sediments are accumulated, and (3) zone of current equilibrium (C), where the sediments are distributed as a shoreline at the boundary of the estuarine delta. The estuary sedimentology dynamics collects and keeps the record of the geologic unit material crossed by Ma'adim Vallis, and those of the lakebed deposit of Elysium Basin. The predicted mixed stratigraphic sequence from fluvial and lacustrine sediment makes this site an exceptional environment to concentrate potential multi-origin biologic records. We envision four possible strategies to explore this sedimentologic record: (1) longitudinal surface and subsurface traverses in region A to investigate outcrop levees, (2) exploration of the mesa walls in region B, (3) deep drilling hole lodging of the sequential deposits in the zones A and B, and (4) surface and subsurface exploration of the shoreline delta. The expected results for each of these strategies are: (1) in the deepest

  12. Exploring the water storage changes in the largest lake (Selin Co) over the Tibetan Plateau during 2003-2012 from a basin-wide hydrological modeling

    NASA Astrophysics Data System (ADS)

    Zhou, Jing; Wang, Lei; Zhang, Yinsheng; Guo, Yanhong

    2016-04-01

    Lake water storage change (DSw) is an important indicator of the hydrologic cycle and greatly influences lake expansion/shrinkage over the Tibetan Plateau (TP). Accurate estimation of DSw will contribute to improved understanding of lake variations in the TP. Based on a water balance, this study explored the variations of DSw for the Lake Selin Co (the largest closed lake on the TP) during 2003-2012 using the Water and Energy Budget-based Distributed Hydrological Model (WEB-DHM) together with two different evapotranspiration (ET) algorithms (the Penman-Monteith method and a simple sublimation estimation approach for water area in unfrozen and frozen period). The contributions of basin discharge and climate causes to the DSw are also quantitatively analyzed. The results showed that WEB-DHM could well reproduce daily discharge, the spatial pattern, and basin-averaged values of MODIS land surface temperature (LST) during nighttime and daytime. Compared with the ET reference values estimated from the basin-wide water balance, our ET estimates showed better performance than three global ET products in reproducing basin-averaged ET. The modeled ET at point scale matches well with short-term in situ daily measurements (RMSE=0.82 mm/d). Lake inflows and precipitation over the water area had stronger relationships with DSw in the warm season and monthly scale, whereas evaporation from the water area had remarkable effects on DSw in the cold season. The total contribution of the three factors to DSw was about 90%, and accounting for 49.5%, 22.1%, and 18.3%, respectively.

  13. Exploring the water storage changes in the largest lake (Selin Co) over the Tibetan Plateau during 2003-2012 from a basin-wide hydrological modeling

    NASA Astrophysics Data System (ADS)

    Zhou, J.; Wang, L.; Zhang, Y.

    2015-12-01

    Lake water storage changes (ΔSw) is an important indicator of the hydrologic cycle and greatly influences lake expansion/shrinkage over the Tibetan Plateau (TP). Accurate estimation of ΔSw will contribute to an improved understanding of lake variations in the TP. Based on water balance, this study explored the variations of ΔSw for the Lake Selin Co (the largest closed lake on the TP) during 2003-2012 using the Water and Energy Budget-based Distributed Hydrological Model (WEB-DHM) together with two different evapotranspiration (ET) algorithms (the Penman-Monteith method and a simple sublimation estimation approach for water area in unfrozen and frozen period). The contributions of basin discharge and climate causes to the ΔSw are also quantitatively analyzed. The result shows that WEB-DHM can well reproduce daily discharges at two gauges. Both daytime and nighttime land surface temperature (LST) simulated by the WEB-DHM agreed well with MODIS LST for both basin-averaged values and spatial patterns. Compared with the ET reference values estimated from the basin-wide water balance, ET estimates in this study showed better performance than three global ET products in reproducing basin-averaged ET. The modeled ET at point scale matches well with short-term in situ daily measurements. Lake inflows and precipitation over the water area had stronger relationships with ΔSw in warm season and monthly scale, whereas ET from the water area had remarkable effects on ΔSw in cold season. The above three factors contributed about 87% of the total changes of ΔSw during 2003-2012.

  14. Exploring the water storage changes in the largest lake (Selin Co) over the Tibetan Plateau during 2003-2012 from a basin-wide hydrological modeling

    NASA Astrophysics Data System (ADS)

    Zhou, Jing; Wang, Lei; Zhang, Yinsheng; Guo, Yanhong; Li, Xiuping; Liu, Wenbin

    2015-10-01

    Lake water storage change (ΔSw) is an important indicator of the hydrologic cycle and greatly influences lake expansion/shrinkage over the Tibetan Plateau (TP). Accurate estimation of ΔSw will contribute to improved understanding of lake variations in the TP. Based on a water balance, this study explored the variations of ΔSw for the Lake Selin Co (the largest closed lake on the TP) during 2003-2012 using the Water and Energy Budget-based Distributed Hydrological Model (WEB-DHM) together with two different evapotranspiration (ET) algorithms (the Penman-Monteith method and a simple sublimation estimation approach for water area in unfrozen and frozen period). The contributions of basin discharge and climate causes to the ΔSw are also quantitatively analyzed. The results showed that WEB-DHM could well reproduce daily discharge, the spatial pattern, and basin-averaged values of MODIS land surface temperature (LST) during nighttime and daytime. Compared with the ET reference values estimated from the basin-wide water balance, our ET estimates showed better performance than three global ET products in reproducing basin-averaged ET. The modeled ET at point scale matches well with short-term in situ daily measurements (RMSE = 0.82 mm/d). Lake inflows and precipitation over the water area had stronger relationships with ΔSw in the warm season and monthly scale, whereas evaporation from the water area had remarkable effects on ΔSw in the cold season. The total contribution of the three factors to ΔSw was about 90%, and accounting for 49.5%, 22.1%, and 18.3%, respectively.

  15. Attenuation in Railroad Valley, Nye County, eastern Nevada, and its significance for petroleum exploration in the eastern Great Basin

    SciTech Connect

    Walker, C.T.; Francis, R.D.

    1996-12-31

    Data from over 100 wells suggest that the boundary between the Grant Range and Railroad Valley is a low angle detachment fault at or close to a metamorphic core complex. The White Pine Detachment, mapped previously in the White Pine and Grant Ranges, is penetrated by many wells because it occurs at a high structural level. A structure contour map based on both surface and subsurface data indicates that the detachment dips uniformly into the subsurface and is not displaced significantly by a high angle fault. In the Grant Range subparallel detachments are developed in the more ductile units. Because the White Pine Detachment is not displaced by high angle faults Railroad Valley cannot have formed by steep normal faulting but instead by attenuation along a series of subparallel detachments. Generation and accumulation of hydrocarbons in Railroad Valley and similar basins may be related to the attenuation that created the basins. For example, the extent to which attenuation juxtaposed potential source rocks and hot infrastructure rocks may influence maturity. Consequently, areas normally considered too shallow for petroleum generation should not necessarily be discounted. Furthermore, failure to find petroleum in a favorable structure may not mean that the basin lacks potential because, as in Railroad Valley, source rocks may be locally absent as a result of attenuation. Reservoir structures formed by attenuation, such as lenticular stretch structures and localized fracture zones in otherwise impermeable formations, may exist.

  16. Attenuation in Railroad Valley, Nye County, eastern Nevada, and its significance for petroleum exploration in the eastern Great Basin

    SciTech Connect

    Walker, C.T.; Francis, R.D. )

    1996-01-01

    Data from over 100 wells suggest that the boundary between the Grant Range and Railroad Valley is a low angle detachment fault at or close to a metamorphic core complex. The White Pine Detachment, mapped previously in the White Pine and Grant Ranges, is penetrated by many wells because it occurs at a high structural level. A structure contour map based on both surface and subsurface data indicates that the detachment dips uniformly into the subsurface and is not displaced significantly by a high angle fault. In the Grant Range subparallel detachments are developed in the more ductile units. Because the White Pine Detachment is not displaced by high angle faults Railroad Valley cannot have formed by steep normal faulting but instead by attenuation along a series of subparallel detachments. Generation and accumulation of hydrocarbons in Railroad Valley and similar basins may be related to the attenuation that created the basins. For example, the extent to which attenuation juxtaposed potential source rocks and hot infrastructure rocks may influence maturity. Consequently, areas normally considered too shallow for petroleum generation should not necessarily be discounted. Furthermore, failure to find petroleum in a favorable structure may not mean that the basin lacks potential because, as in Railroad Valley, source rocks may be locally absent as a result of attenuation. Reservoir structures formed by attenuation, such as lenticular stretch structures and localized fracture zones in otherwise impermeable formations, may exist.

  17. Southeastern extension of the Lake Basin fault zone in south- central Montana: implications for coal and hydrocarbon exploration ( USA).

    USGS Publications Warehouse

    Robinson, L.N.; Barnum, B.E.

    1986-01-01

    The Lake Basin fault zone consists mainly of en echelon NE-striking normal faults that have been interpreted to be surface expressions of left-lateral movement along a basement wrench fault. Information gathered from recent field mapping of coal beds and from shallow, closely-spaced drill holes resulted in detailed coal bed correlations, which revealed another linear zone of en echelon faulting directly on the extended trend of the Lake Basin fault zone. This faulted area, referred to as the Sarpy Creek area, is located 48 km E of Hardin, Montana. It is about 16 km long, 13 km wide, and contains 21 en echelon normal faults that have an average strike of N 63oE. We therefore extend the Lake Basin fault zone 32 km farther SE than previously mapped to include the Sarpy Creek area. The Ash Creek oil field, Wyoming, 97 km due S of the Sarpy Creek area, produces from faulted anticlinal structues that have been interpreted to be genetically related to the primary wrench-fault system known as the Nye-Bowler fault zone. The structural similarities between the Sarpy Creek area and the Ash Creek area indicate that the Sarpy Creek area is a possible site for hydrocarbon accumulation.-from Authors

  18. Dickinson field lodgepole reservoir: Significance of this Waulsortian-type mound to exploration in the Williston Basin

    SciTech Connect

    Johnson, M.S.

    1995-07-01

    Conoco`s No. 74 Dickinson State well, a deep test in Dickinson Field, Stark County, North Dakota, was completed in early 1993 capable of producing over 2,000 BOPD. It represents the first commercial oil production from the Lower Mississippian Lodgepole Formation in the U.S. portion of the Williston Basin. Three additional oil producers have now been completed and this Lodgepole discovery is fully developed. The producing reservoir, at depths of 9,700 to 10,000 ft, is a Waulsortian-type mound approximately 300 ft thick with a characteristic faunal assemblage of bryozoans and crinoids. The mound has an areal extent of slightly more than 1 square mile. Similar Waulsortian-type mounds have been recognized in rocks of Paleozoic age around the world, but have only been reported in the Williston Basin during the past decade. Such mounds are shallow to deep water deposits, tend to develop over structurally or topographically-positive areas, and may form by algal or by current action in conjunction with baffling action caused by bryozoans. The prolific nature of the Conoco discovery, plus several more-recent excellent mound discoveries in this same area, have caused renewed drilling and leasing activity. These events have also encouraged a review of existing seismic data, the shooting of new 3-D seismic programs and re-analysis of wells previously drilled through the Lodgepole Formation for evidence of similar mounds elsewhere in the basin.

  19. 40 CFR 81.191 - Appalachian Intrastate Air Quality Control Region.

    Code of Federal Regulations, 2010 CFR

    2010-07-01

    ... Quality Control Regions § 81.191 Appalachian Intrastate Air Quality Control Region. The Appalachian... 40 Protection of Environment 17 2010-07-01 2010-07-01 false Appalachian Intrastate Air Quality Control Region. 81.191 Section 81.191 Protection of Environment ENVIRONMENTAL PROTECTION AGENCY...

  20. 40 CFR 81.191 - Appalachian Intrastate Air Quality Control Region.

    Code of Federal Regulations, 2011 CFR

    2011-07-01

    ... Quality Control Regions § 81.191 Appalachian Intrastate Air Quality Control Region. The Appalachian... 40 Protection of Environment 17 2011-07-01 2011-07-01 false Appalachian Intrastate Air Quality Control Region. 81.191 Section 81.191 Protection of Environment ENVIRONMENTAL PROTECTION AGENCY...

  1. 40 CFR 81.191 - Appalachian Intrastate Air Quality Control Region.

    Code of Federal Regulations, 2012 CFR

    2012-07-01

    ... Quality Control Regions § 81.191 Appalachian Intrastate Air Quality Control Region. The Appalachian... 40 Protection of Environment 18 2012-07-01 2012-07-01 false Appalachian Intrastate Air Quality Control Region. 81.191 Section 81.191 Protection of Environment ENVIRONMENTAL PROTECTION AGENCY...

  2. 40 CFR 81.191 - Appalachian Intrastate Air Quality Control Region.

    Code of Federal Regulations, 2014 CFR

    2014-07-01

    ... Quality Control Regions § 81.191 Appalachian Intrastate Air Quality Control Region. The Appalachian... 40 Protection of Environment 18 2014-07-01 2014-07-01 false Appalachian Intrastate Air Quality Control Region. 81.191 Section 81.191 Protection of Environment ENVIRONMENTAL PROTECTION AGENCY...

  3. 75 FR 3224 - Dominion Transmission, Inc.; Notice of Public Scoping Meetings for the Appalachian Gateway Project

    Federal Register 2010, 2011, 2012, 2013, 2014

    2010-01-20

    ... firm transportation services from increasing gas production in the Appalachian region of West Virginia... Appalachian Gateway Project January 8, 2010. The staff of the Federal Energy Regulatory Commission (FERC or... Appalachian Gateway Project involving construction and operation of facilities by Dominion Transmission,...

  4. 40 CFR 81.191 - Appalachian Intrastate Air Quality Control Region.

    Code of Federal Regulations, 2013 CFR

    2013-07-01

    ... Quality Control Regions § 81.191 Appalachian Intrastate Air Quality Control Region. The Appalachian... 40 Protection of Environment 18 2013-07-01 2013-07-01 false Appalachian Intrastate Air Quality Control Region. 81.191 Section 81.191 Protection of Environment ENVIRONMENTAL PROTECTION AGENCY...

  5. Appalachian Literature and Culture: A Teaching Unit for High School Students.

    ERIC Educational Resources Information Center

    Brennan, Joan M.

    A 10-week unit of study of Appalachian literature and culture, focusing on Harriette Arnow's novel, "The Dollmaker," is designed to deepen Appalachian students' awareness of their rich cultural heritage as well as to encourage non-Appalachians' appreciation of backgrounds different from their own. One week is allotted for teacher-presented…

  6. Exploring the Geomorphology of the Amazon's Planalto with Imaging Radar: Understanding the Origins of the Modern Amazon Basin

    NASA Astrophysics Data System (ADS)

    McDonald, K. C.; Campbell, K.; Islam, R.; Azarderakhsh, M.; Cracraft, J.

    2013-12-01

    Amazonia is Earth's most iconic center of biological diversity and endemism and, owing to its contributions to global systems ecology, is arguably Earth's most important terrestrial biome . Amazonia includes a vast landscape of mostly lowland rainforest found in Brazil, Peru, Colombia, Ecuador, Bolivia, and Venezuela. It harbors the world's highest species diversity, the largest fresh-water ecosystem in the world, and contributes substantially to shaping the Earth's atmospheric gasses and oceans and consequently its climate. Despite this global importance, we still have an incomplete understanding of how this biodiversity-rich biome developed over time. Knowing its history is crucially important for understanding how the short and long-term effects of biodiversity loss and climate change will impact the region, and the globe, in the future. Hence, we seek to understand the evolutionary and environmental-ecological history of Amazonia over the past 10 million years through a comparative approach that integrates across the disciplines of systematic biology, population biology, ecosystem structure and function, geology, Earth systems modeling and remote sensing, and paleoenvironmental history. During springtime 2013, the NASA/JPL airborne imaging radar, UAVSAR, conducted airborne studies over many regions of South America including portions of the western Amazon basin. We utilize UAVSAR imagery acquired over the Madre de Dios region of southeastern Peru in an assessment of the underlying geomorphology of the Amazon's planalto, its relationship to the current distribution of vegetation, and its relationship to geologic processes through deep time. In the late Neogene, the Amazonian lowlands comprised either a series of independent basins or a single sedimentary basin. The Amazonian planalto is variously described as either an erosional surface or a surface of deposition. We employ UAVSAR data collections to assess (1) the utility of these high quality imaging radar

  7. Evidence for long-term climate change in Upper Devonian strata of the central Appalachians

    USGS Publications Warehouse

    Brezinski, D.K.; Cecil, C.B.; Skema, V.W.; Kertis, C.A.

    2009-01-01

    The highest 1 to 200 m of the Upper Devonian (Famennian) Catskill and equivalent Hampshire formations exhibit a noticeable vertical or stratigraphic change in color and a shift in lithologic character. The lower part of the unit is characterized by typically red, channel-phase sandstones and overbank siltstone and mudstone containing thin calcareous paleosols. These lithologies give way to greenish gray sandstone containing abundant coaly plant fragments, coalified logs, and pyrite, interbedded with thick intervals of non-calcareous paleo-vertisols. The increase in the prominence of preserved terrestrial organic matter suggests that there was a corresponding increase in the abundance of plants in terrestrial ecosystems. The stratigraphic change in lithology within the upper part of the Catskill-Hampshire succession suggests the onset of environmental conditions that became increasingly wet in response to elevated humid climatic conditions during the final stages of Catskill alluvial plain deposition. The sedimentological signature suggesting increased climatic wetness within the uppermost Catskill and Hampshire formations is nearly contemporaneous with the initiation of Late Devonian Gondwanan glaciation in the paleo-high-latitudes. The Appalachian climate record indicates that this change began during the Fa2c and continued through the latest Famennian, reaching its peak during the Fa2d when glacial deposits are recorded in the paleo-mid-latitudes of the Appalachian basin. Evidence of this late Famennian increase in precipitation also is recorded in the adjacent marine environments. Equivalent-age marine units in Ohio and Kentucky record progressive increases in both total organic carbon and the percentage of terrestrially-derived organic carbon. This suggests that there was a late Famennian increase in terrestrial organic matter productivity, and that during the late Famennian, there were elevated levels of runoff produced by the interpreted increase in

  8. Arsenic in groundwaters in the Northern Appalachian Mountain belt: a review of patterns and processes.

    PubMed

    Peters, Stephen C

    2008-07-29

    basins, e.g. the Newark Basin. There are only two well-known cases of anthropogenic contamination of the environment in the northern Appalachian Mountain belt, both of which are industrial sites with surface contamination at that infiltrated the local groundwater.

  9. Arsenic in groundwaters in the Northern Appalachian Mountain belt: A review of patterns and processes

    NASA Astrophysics Data System (ADS)

    Peters, Stephen C.

    2008-07-01

    Naturally occurring arsenic in the bedrock of the Northern Appalachian Mountain belt was first recognized in the late 19th century. The knowledge of the behavior of arsenic in groundwater in this region has lagged behind nearly a century, with the popular press reporting on local studies in the early 1980s, and most peer-reviewed research articles on regional patterns conducted and written in the late 1990s and early 2000s. Research reports have shown that within this high arsenic region, between 6% and 22% of households using private drinking water wells contain arsenic in excess of 10 µg/L, the United States Environmental Protection Agency's maximum contaminant level. In nearly all reports, arsenic in drinking water was derived from naturally occurring geologic sources, typically arsenopyrite, substituted sulfides such as arsenian pyrite, and nanoscale minerals such as westerveldite. In most studies, arsenic concentrations in groundwater were controlled by pH dependent adsorption to mineral surfaces, most commonly iron oxide minerals. In some cases, reductive dissolution of iron minerals has been shown to increase arsenic concentrations in groundwater, more commonly associated with anthropogenic activities such as landfills. Evidence of nitrate red