ALBERT

All Library Books, journals and Electronic Records Telegrafenberg

feed icon rss

Ihre E-Mail wurde erfolgreich gesendet. Bitte prüfen Sie Ihren Maileingang.

Leider ist ein Fehler beim E-Mail-Versand aufgetreten. Bitte versuchen Sie es erneut.

Vorgang fortführen?

Exportieren
  • 1
    Schriftenreihen ausleihbar
    Schriftenreihen ausleihbar
    Washington, DC : United States Gov. Print. Off.
    Dazugehörige Bände
    Signatur: SR 90.0001(1866-H)
    In: U.S. Geological Survey bulletin
    Materialart: Schriftenreihen ausleihbar
    Seiten: IV, H-19 S.
    Serie: U.S. Geological Survey bulletin 1866-H
    Sprache: Englisch
    Standort: Kompaktmagazin unten
    Zweigbibliothek: GFZ Bibliothek
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 2
    Signatur: SR 90.0001(1787-G)
    In: U.S. Geological Survey bulletin
    Materialart: Schriftenreihen ausleihbar
    Seiten: V, G-31 S. + 1 pl.
    Serie: U.S. Geological Survey bulletin 1787-G
    Sprache: Englisch
    Standort: Kompaktmagazin unten
    Zweigbibliothek: GFZ Bibliothek
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 3
    Publikationsdatum: 2006-06-01
    Beschreibung: We thank Tom Ewing for his informative discussion to our recent article on the Barnett Shale. Ewing provides an excellent, useful review of geologic data concerning uplift and burial history in the Fort Worth basin. His discussion of this specific topic improves upon our own, adding significant detail that should aid future analyses of the Barnett. In particular, his inclusion of a major Mesozoic erosional event as a correction to our burial history curve for Eastland County (figure 7) is welcome. We also credit Ewing for noting the limits to existing data. He emphasizes that the amount of late Paleozoic subsidence and the precise timing of post-Permian uplift remain unknown, and that, as a consequence, reconstructions of burial history must therefore include both facts and inferences. At the same time, we find problematic other interpretations in Ewing's discussion. One of these involves the use of burial history information (sedimentary and tectonic loading) to explain maturation patterns in the Barnett Shale. The other issue of concern relates to the westward extent of Ouachita thrusting. As emphasized in our article, Barnett maturity levels in many parts of the Fort Worth basin are too high and variable to be explained by the present-day basin setting. No consistent relationship exists between depth …
    Print ISSN: 0149-1423
    Digitale ISSN: 1943-2674
    Thema: Geologie und Paläontologie
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 4
    Publikationsdatum: 2007-04-01
    Beschreibung: This article describes the primary geologic characteristics and criteria of the Barnett Shale and Barnett-Paleozoic total petroleum system (TPS) of the Fort Worth Basin used to define two geographic areas of the Barnett Shale for petroleum resource assessment. From these two areas, referred to as “assessment units,” the U.S. Geological Survey estimated a mean volume of about 26 tcf of undiscovered, technically recoverable hydrocarbon gas in the Barnett Shale. The Mississippian Barnett Shale is the primary source rock for oil and gas produced from Paleozoic reservoir rocks in the Bend arch–Fort Worth Basin area and is also one of the most significant gas-producing formations in Texas. Subsurface mapping from well logs and commercial databases and petroleum geochemistry demonstrate that the Barnett Shale is organic rich and thermally mature for hydrocarbon generation over most of the Bend arch–Fort Worth Basin area. In the northeastern and structurally deepest part of the Fort Worth Basin adjacent to the Muenster arch, the formation is more than 1000 ft (305 m) thick and interbedded with thick limestone units; westward, it thins rapidly over the Mississippian Chappel shelf to only a few tens of feet. The Barnett-Paleozoic TPS is identified where thermally mature Barnett Shale has generated large volumes of hydrocarbons and is (1) contained within the Barnett Shale unconventional continuous accumulation and (2) expelled and distributed among numerous conventional clastic- and carbonate-rock reservoirs of Paleozoic age. Vitrinite reflectance (Ro) measurements show little correlation with present-day burial depth. Contours of equal Ro values measured from Barnett Shale and typing of produced hydrocarbons indicate significant uplift and erosion. Furthermore, the thermal history of the formation was enhanced by hydrothermal events along the Ouachita thrust front and Mineral Wells–Newark East fault system. Stratigraphy and thermal maturity define two gas-producing assessment units for the Barnett Shale: (1) a greater Newark East fracture-barrier continuous Barnett Shale gas assessment unit, encompassing an area of optimal gas production where dense impermeable limestones enclose thick (≥300 ft; ≥91 m) Barnett Shale that is within the gas-generation window (Ro ≥ 1.1%); and (2) an extended continuous Barnett Shale gas assessment unit covering an area where the Barnett Shale is within the gas-generation window, but is less than 300 ft (91 m) thick, and either one or both of the overlying and underlying limestone barriers are absent. Rich Pollastro received an M.A. degree in geology from the State University of New York at Buffalo in 1977. Rich joined the U.S. Geological Survey in 1978 and serves as a province geologist on the national and world energy assessment projects. His recent accomplishments include petroleum system assessments of the Fort Worth, Permian, and South Florida basins and the Arabian Peninsula. Dan Jarvie is an organic geochemist and president of Humble Geochemical Services. Dan earned his B.S. degree from the University of Notre Dame and was mentored in geochemistry by Don Baker and Wallace Dow. He has studied unconventional oil and gas systems extensively since 1984. Dan's work on the Barnett Shale spans much of the last decade, which has resulted in several AAPG awards. Ronald Hill specializes in petroleum geochemistry and has more than 12 years of oil industry experience. Currently, he is a research geologist for the U.S. Geological Survey. His research interests include shale-gas resources and processes that control petroleum generation. Ron holds geology degrees from the Michigan State University (B.S. degree) and the University of California, Los Angeles (Ph.D.), and a geochemistry degree from the Colorado School of Mines (M.S. degree). Craig Adams worked as an exploration geologist with Amoco Production Company for 13 years before becoming an independent in 1996. As president and co-owner of Adexco Production Company, his primary focus is conventional and unconventional oil and gas in Texas and the mid-continent. Craig has worked the Barnett Shale for 6 years, where his company was one of the first to expand beyond the core area of the Newark East field.
    Print ISSN: 0149-1423
    Digitale ISSN: 1943-2674
    Thema: Geologie und Paläontologie
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 5
    Publikationsdatum: 2007-04-01
    Beschreibung: Shale-gas resource plays can be distinguished by gas type and system characteristics. The Newark East gas field, located in the Fort Worth Basin, Texas, is defined by thermogenic gas production from low-porosity and low-permeability Barnett Shale. The Barnett Shale gas system, a self-contained source-reservoir system, has generated large amounts of gas in the key productive areas because of various characteristics and processes, including (1) excellent original organic richness and generation potential; (2) primary and secondary cracking of kerogen and retained oil, respectively; (3) retention of oil for cracking to gas by adsorption; (4) porosity resulting from organic matter decomposition; and (5) brittle mineralogical composition. The calculated total gas in place (GIP) based on estimated ultimate recovery that is based on production profiles and operator estimates is about 204 bcf/section (5.78 × 109 m3/1.73 × 104 m3). We estimate that the Barnett Shale has a total generation potential of about 609 bbl of oil equivalent/ac-ft or the equivalent of 3657 mcf/ac-ft (84.0 m3/m3). Assuming a thickness of 350 ft (107 m) and only sufficient hydrogen for partial cracking of retained oil to gas, a total generation potential of 820 bcf/section is estimated. Of this potential, approximately 60% was expelled, and the balance was retained for secondary cracking of oil to gas, if sufficient thermal maturity was reached. Gas storage capacity of the Barnett Shale at typical reservoir pressure, volume, and temperature conditions and 6% porosity shows a maximum storage capacity of 540 mcf/ac-ft or 159 scf/ton. Dan Jarvie is an analytical and interpretive organic geochemist. He has worked on conventional hydrocarbon systems and unconventional shale-oil and shale-gas hydrocarbon systems, including the Barnett Shale since 1989. He earned a B.S. degree from the University of Notre Dame and was mentored in geochemistry by Wallace Dow and Don Baker of Rice University. He is president of Humble Geochemical Services. Ronald Hill specializes in petroleum geochemistry and has more than 12 years of professional experience, including those with ExxonMobil and Chevron. Currently, he is a research geologist for the U.S. Geological Survey. His interests include investigation of shale-gas resources and the processes that control petroleum generation. He holds geology degrees from Michigan State University (B.S. degree) and the University of California, Los Angeles (Ph.D.), and a geochemistry degree from the Colorado School of Mines (M.S. degree). Tim Ruble is a petroleum geochemist with Humble Geochemical Services and is currently involved in studies focused on the assessment of shale-gas resources. He has had a diverse professional career that has included periods with the Commonwealth Scientific and Industrial Research Organization in Australia, Mobil Oil, and the U.S. Geological Survey. He has published on a variety of geochemical topics, including lacustrine petroleum systems, oil-bearing fluid inclusions, native bitumens, biomarker analyses, and hydrocarbon generation kinetics. Tim earned his B.S. degree in chemistry from Truman State University and his M.S. degree and his Ph.D. in geology from the University of Oklahoma. Richard Pollastro received an M.A. degree in geological science from the State University of New York at Buffalo in 1977. He joined the U.S. Geological Survey in 1978 and has served as a province geologist on the national and world energy assessment projects. His recent accomplishments include petroleum system analysis and resource assessment of the Bend arch–Fort Worth Basin, with particular focus on Barnett Shale, South Florida Basin, and the Arabian Peninsula.
    Print ISSN: 0149-1423
    Digitale ISSN: 1943-2674
    Thema: Geologie und Paläontologie
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 6
    Publikationsdatum: 2005-02-01
    Beschreibung: The Mississippian Barnett Shale serves as source, seal, and reservoir to a world-class unconventional natural-gas accumulation in the Fort Worth basin of north-central Texas. The formation is a lithologically complex interval of low permeability that requires artificial stimulation to produce. At present, production is mainly confined to a limited portion of the northern basin where the Barnett Shale is relatively thick (〉300 ft; 〉92 m), organic rich (present-day total organic carbon 〉 3.0%), thermally mature (vitrinite reflectance 〉 1.1%), and enclosed by dense limestone units able to contain induced fractures. The most actively drilled area is Newark East field, currently the largest gas field in Texas. Newark East is 400 mi2 (1036 km2) in extent, with more than 2340 producing wells and about 2.7 tcf of booked gas reserves. Cumulative gas production from Barnett Shale wells through 2003 was about 0.8 tcf. Wells in Newark East field typically produce from depths of 7500 ft (2285 m) at rates ranging from 0.5 to more than 4 mmcf/day. Estimated ultimate recoveries per well range from 0.75 to as high as 7.0 bcf. Efforts to extend the current Barnett play beyond the field limits have encountered several challenges, including westward and northward increases in oil saturation and the absence of lithologic barriers to induced fracture growth. Patterns of oil and gas occurrence in the Barnett, in conjunction with maturation and burial-history data, indicate a complex, multiphased thermal evolution, with episodic expulsion of hydrocarbons and secondary cracking of primary oils to gas in portions of the basin where paleotemperatures were especially elevated. These and other data imply a large-potential Barnett resource for the basin as a whole (possibly 〉200 tcf gas in place). Recent assessment by the U.S. Geological Survey suggests a mean volume of 26.2 tcf of undiscovered, technically recoverable gas in the central Fort Worth basin. Recovery of a significant portion of this undiscovered resource will require continued improvements in geoscientific characterization and approaches to stimulation of the Barnett reservoirs. Scott L. Montgomery is a petroleum consultant and author residing in Seattle, Washington. He holds a B.A. degree in English from Knox College (1973) and an M.S. degree in geological sciences from Cornell University (1978). He is the lead author for the Petroleum Frontiers monograph series, published by IHS Energy Group, and has published widely on topics in the petroleum industry.Dan Jarvie is an analytical and interpretive organic geochemist. He has worked on conventional petroleum systems and, since 1984, unconventional oil and gas systems as well. His work on the Barnett Shale spans much of the last decade. He earned a B.S. degree from the University of Notre Dame and was mentored in geochemistry by Don Baker of Rice University and Wallace Dow. He is president of Humble Geochemical Services. Kent drilled his first Barnett well in 1997 while employed with Chevron U.S.A., as a member of the company's Nonconventional Gas Business Team. He subsequently transferred to Mitchell Energy, where he was involved in the drilling of more than a thousand Barnett wells. Currently, Kent is with Star of Texas Energy Services, Inc., which is also active in the Barnett Shale play. He is a certified and registered (Texas and Wyoming) petroleum geologist. Richard Pollastro received an M.A. degree in geological science from the State University of New York at Buffalo in 1977. He joined the U.S. Geological Survey in 1978 and has served as a province geologist on the national and world energy assessment projects. His recent accomplishments include petroleum system analysis and resource assessments of the Bend arch–Fort Worth basin with particular focus on Barnett Shale, South Florida basin, and the Arabian Peninsula.
    Print ISSN: 0149-1423
    Digitale ISSN: 1943-2674
    Thema: Geologie und Paläontologie
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 7
    Publikationsdatum: 2007-04-01
    Beschreibung: Undiscovered natural gas having potential for additions to reserves in the Mississippian Barnett Shale of the Fort Worth Basin, north-central Texas, was assessed using the total petroleum system assessment unit concept and a cell-based methodology for continuous-type (unconventional) resources. The Barnett-Paleozoic total petroleum system is defined in the Bend arch–Fort Worth Basin as encompassing the area in which the organic-rich Barnett is the primary source rock for oil and gas produced from Paleozoic carbonate and clastic reservoirs. Exploration, technology, and drilling in the Barnett Shale play have rapidly evolved in recent years, with about 3500 vertical and 1000 horizontal wells completed in the Barnett through 2005 and more than 85% of the them completed since 1999. Using framework geology and historical production data, assessment of the Barnett Shale was performed by the U.S. Geological Survey using vertical wells at the peak of vertical well completions and before a transition to completions with horizontal wells. The assessment was performed after (1) mapping critical geological and geochemical parameters to define assessment unit areas with future potential, (2) defining distributions of drainage area (cell size) and estimating ultimate recovery per cell, and (3) estimating future success rates. Two assessment units are defined and assessed for the Barnett Shale continuous gas accumulation, resulting in a total mean undiscovered volume having potential for additions to reserves of 26.2 TCFG. The greater Newark East fracture-barrier continuous Barnett Shale gas assessment unit represents a core-producing area where thick, organic-rich, siliceous Barnett Shale is within the thermal window for gas generation (Ro ≥ 1.1%) and is overlain and underlain by impermeable limestone barriers (Pennsylvanian Marble Falls Limestone and Ordovician Viola Limestone, respectively) that serve to confine induced fractures during well completion to maximize gas recovery. The extended continuous Barnett Shale gas assessment unit, which had been less explored, defines a geographic area where Barnett Shale is (1) within the thermal window for gas generation, (2) greater than 100 ft (30 m) thick, and (3) where at least one impermeable limestone barrier is absent. Mean undiscovered gas having potential for additions to reserves in the greater Newark East assessment unit is estimated at 14.6 tcf, and in the less tested extended assessment unit, a mean resource is estimated at 11.6 TCFG. A third hypothetical basin-arch Barnett Shale oil assessment unit was defined but not assessed because of a lack of production data. Rich received an M.A. degree in geology from the State University of New York at Buffalo in 1977. He joined the U.S. Geological Survey in 1978 and serves as a province geologist on the national and world energy assessment projects. His recent accomplishments include petroleum system assessments of the Fort Worth, Permian, and South Florida basins, and the Arabian Peninsula.
    Print ISSN: 0149-1423
    Digitale ISSN: 1943-2674
    Thema: Geologie und Paläontologie
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 8
    Publikationsdatum: 2007-04-01
    Beschreibung: Detailed biomarker and light hydrocarbon geochemistry confirm that the marine Mississippian Barnett Shale is the primary source rock for petroleum in the Fort Worth Basin, north-central Texas, although contributions from other sources are possible. Biomarker data indicate that the main oil-generating Barnett Shale facies is marine and was deposited under dysoxic, strong upwelling, normal salinity conditions. The analysis of two outcrop samples and cuttings from seven wells indicates variability in the Barnett Shale organic facies and a possibility of other oil subfamilies being present. Light hydrocarbon analyses reveal significant terrigenous-sourced condensate input to some reservoirs, resulting in terrigenous and mixed marine-terrigenous light hydrocarbon signatures for many oils. The light hydrocarbon data suggest a secondary, condensate-generating source facies containing terrigenous or mixed terrigenous-marine organic matter. This indication of a secondary source rock that is not revealed by biomarker analysis emphasizes the importance of integrating biomarker and light hydrocarbon data to define petroleum source rocks. Gases in the Fort Worth Basin are thermogenic in origin and appear to be cogenerated with oil from the Barnett Shale, although some gas may also originate by oil cracking. Isotope data indicate minor contribution of biogenic gas. Except for reservoirs in the Pennsylvanian Bend Group, which contain gases spanning the complete range of observed maturities, the gases appear to be stratigraphically segregated, younger reservoirs contain less mature gas, and older reservoirs contain more mature gas. We cannot rule out the possibility that other source units within the Fort Worth Basin, such as the Smithwick Shale, are locally important petroleum sources. Ronald Hill specializes in petroleum geochemistry and has more than 12 years of professional experience, which includes his years in ExxonMobil and Chevron. Currently, he is a research geologist for the U.S. Geological Survey. His interests include the investigation of shale-gas resources and the processes that control petroleum generation. He holds geology degrees from the Michigan State University (B.S. degree), the University of California, Los Angeles (Ph.D.), and a geochemistry degree from the Colorado School of Mines (M.S. degree). Dan Jarvie is an analytical and interpretive organic geochemist. He works on conventional hydrocarbon systems and has worked on unconventional shale-oil and shale-gas hydrocarbon systems since 1984 and the Barnett Shale since 1989. He earned a B.S. degree from the University of Notre Dame and was mentored in geochemistry by Wallace Dow and Don Baker of Rice University. He is the president of Humble Geochemical Services. John E. Zumberge is a cofounder of GeoMark Research in Houston and has been vice president since GeoMark was founded in 1991. He was manager of geochemical and geological research for Cities Service–Occidental, general manager for Ruska Laboratories, and director of geochemical services for Core Laboratories. He has global experience in petroleum geochemistry, focusing on crude-oil biomarkers. He obtained a B.S. degree in chemistry from the University of Michigan and a Ph.D. in organic geochemistry from the University of Arizona. Mitchell Henry received a Bachelor of Science degree in biology from Midwestern University, Wichita Falls, Texas, in 1969. He was awarded a Master of Science degree in Oceanography from Texas A&M University, College Station, Texas, in 1974, and earned a Ph.D. also from Texas A&M in 1982. He joined the U.S. Geological Survey in 1974 and retired from that organization in 2005. His primary interests were in remote sensing, direct detection of geochemical anomalies related to petroleum microseepage, and the application of computer analysis to basin studies. His most recent assignments were related to domestic and international petroleum resource assessments, basin analysis, and hydrocarbon source rock studies. Rich Pollastro received an M.A. degree in geology from the State University of New York at Buffalo in 1977. Rich joined the U.S. Geological Survey in 1978 and serves as a province geologist on the national and world energy assessment projects. His recent accomplishments include petroleum system assessments of the Fort Worth, Permian, and South Florida basins and the Arabian Peninsula.
    Print ISSN: 0149-1423
    Digitale ISSN: 1943-2674
    Thema: Geologie und Paläontologie
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 9
    Publikationsdatum: 1994-01-01
    Print ISSN: 0009-8604
    Digitale ISSN: 1552-8367
    Thema: Geologie und Paläontologie
    Publiziert von Clay Minerals Society
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
  • 10
    Publikationsdatum: 1985-01-01
    Print ISSN: 0009-8604
    Digitale ISSN: 1552-8367
    Thema: Geologie und Paläontologie
    Publiziert von Clay Minerals Society
    Standort Signatur Erwartet Verfügbarkeit
    BibTip Andere fanden auch interessant ...
Schließen ⊗
Diese Webseite nutzt Cookies und das Analyse-Tool Matomo. Weitere Informationen finden Sie hier...