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all geography including DSDP/ODP Sites and Legs
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carbon
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upper Quaternary
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Tertiary
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Neogene
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Chordata
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Upper Cretaceous
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Jurassic
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metal ores
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secondary structures
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sediments
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sediments
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clastic sediments
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soils (1)
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Sublette County Wyoming
Applying Waveform Correlation to Reduce Seismic Analyst Workload Due to Repeating Mining Blasts
Patterns of incision and deformation on the southern flank of the Yellowstone hotspot from terraces and topography
Along-strike variability of thrust fault vergence
C 13 and Thomsen anisotropic parameter distributions for hydraulic fracture monitoring
Abstract Improved geologic insights combined with advances in technology and innovative thinking, mainly since the laste 1990s, have driven Pinedale field’s development and unlocked a giant natural gas resource in stacked low-permeability fluvial sandstones. Understanding this field can provide a model for developing similar tight sandstone reservoirs around the world. This memoir contains 15 well-illustrated, peer reviewed chapters that describe the history of field development, the deposition and diagenesis of the reservoir rocks, geophysical characteristics of the field, special core analysis techniques used to better quantify the reservoir, petrophysical characteristics and interpretations of the reservoir, the types and abundance of natural fractures, and fluid production characteristics in the field. Finally, static and dynamic models for the field are presented in an attempt to integrate all the pieces of this giant geologic puzzle.
Abstract A synthesis of low-temperature thermochronologic results throughout the Laramide foreland illustrates that samples from wellbores in Laramide basins record either (1) detrital Laramide or older cooling ages in the upper ~1 km (0.62 mi) of the wellbore, with younger ages at greater depths as temperatures increase; or (2) Neogene cooling ages. Surface samples from Laramide ranges typically record either Laramide or older cooling ages. It is apparent that for any particular area the complexity of the cooling history, and hence the tectonic history interpreted from the cooling history, increases as the number of studies or the area covered by a study increases. Most Laramide ranges probably experienced a complex tectono-thermal evolution. Deriving a regional timing sequence for the evolution of the Laramide basins and ranges is still elusive, although a compilation of low-temperature thermochronology data from ranges in the Laramide foreland suggests a younging of the ranges to the south and southwest. Studies of subsurface samples from Laramide basins have, in some cases, been integrated with and used to constrain results from basin burial-history modeling. Current exploration for unconventional shale-oil or shale-gas plays in the Rocky Mountains has renewed interest in thermal and burial history modeling as an aid in evaluating thermal maturity and understanding petroleum systems.This paper suggests that low-temperature thermochronometers are underutilized tools that can provide additional constraints to burial-history modeling and source rock evaluation in the Rocky Mountain region.
The Beaver Creek Detachment System: Syn-Laramide Gravity Detachment and Folding Oblique to Regional Compression
Abstract Detachment folds basinward of Laramide Rocky Mountain arches are relatively poorly known, partially due to coverage by synorogenic strata that may conceal undiscovered anticlinal fields. This study documents the geometry and kinematics of the Beaver Creek Detachment system (BCD), which is located west of a series of NW-trending thrust faults and folds defining the Beaver Creek reentrant on the western edge of the Bighorn Arch. Possible origins for this proposed detachment include syn-Laramide detachment rooted in mountain-front faulting, syn-Laramide gravity slinding during mountain-front folding, and post-Laramide gravity sliding.
Sedimentology, detrital zircon geochronology, and stable isotope geochemistry of the lower Eocene strata in the Wind River Basin, central Wyoming
Predicting permeability and gas production of hydraulically fractured tight sands from microseismic data
Constraining 3D facies modeling by seismic-derived facies probabilities : Example from the tight-gas Jonah Field
Design through interpretation of a very large 3D VSP in a complex area in Jonah Field, Wyoming
Abstract Basin-centered gas models have been proposed to characterize various low-permeability (tight) sandstone gas plays that are an important gas resource found in many Rocky Mountain basins. Recent drilling and three-dimensional seismic results indicate that modifications are required of the currently accepted basin-centered gas models that were first introduced more than 25 yr ago. Current models of basin-centered gas accumulations depict gas trapped below a relatively uniform, enigmatic pressure seal defined by a given structural elevation or thermal-maturation depth that cuts across stratigraphic boundaries. In the prevailing model, this surface separates normally pressured conventional traps from unconventional traps, which are characterized by anomalous reservoir pressure and lack of associated water production. These principles have led to a commonly held misconception that basinwide, commercial gas deposits may exist below this pressure boundary and, further, to predictions of overstated reserves and overly optimistic drilling success rates. New studies of several gas plays in tight sandstones from the Greater Green River Basin in southern Wyoming, reviewed in this chapter, suggest that the primary controls for the occurrence of these fields are better explained as conventional, although subtle, stratigraphic and structural traps. Subsurface data are described, which illustrate additional inconsistencies with the prevalent basin-centered gas models, including the presence of downdip water, and natural fracture and stratigraphic variations that influence productivity. These subtle controls have previously been accepted as poorly understood areas of enhanced production or sweet spots. With a revised understanding, geologic methods can be applied to identify areas of improved reservoir quality, thereby increasing the probability of favorable economic development. More importantly, the key to future exploration success in the Rocky Mountain region and other tight-gas sandstone provinces is recognizing that subtle, conventional stratigraphic and structural traps provide controls on commercial gas deposits in these plays.
Abstract The discovery of a giant natural gas field within a mature petroleum province is a significant event. Understanding the factors that control such an accumulation is important if the oil and gas industry is to continue to develop natural gas resources. Jonah field, in the Greater Green River basin of southwest Wyoming, is the largest natural gas discovery in the onshore United States in the last 10-15 years with recoverable reserves ranging from 8 to 15 tcf natural gas. Since beginning widespread field development in August 1992, Jonah has produced approximately 1 tcf gas, 10.3 million barrels of oil, and 3.7 million barrels of water. Field production is still increasing with daily production presently at 666 MMCFGPD, 5800 BOPD, and 4000 BWPD from approximately 600 wells. Active drilling continues within the field as operators consider widespread downspacing. By virtue of being a tight-gas field, Jonah is, in many respects, nontraditional. Recent assessments of natural gas potential, for both the U.S. and the world, strongly suggest that most future gas resources will come from low-permeability sandstones in the deeper portions of sedimentary basins, and from fields that will undoubtedly share characteristics with Jonah. The subtle structure, the low-permeability nature of the reservoir, the challenging petrophysics, and the environmental sensitivity surrounding Jonah may foreshadow what explorationists have to look forward to as the demand for natural gas increases, not only in the United States, but throughout the world. This volume brings together previously unpublished material on Jonah field and attempts to integrate all aspects including geology, geophysics, reservoir engineering, drilling and completion, and regulatory affairs. As such, this is a definitive collection that provides a truly integrated perspective of this giant field.
Abstract The following information was gathered from various sources and released for publication. Additional information exists among the many operators in Jonah field, but much of that data is considered proprietary. Data on the drilling and completion of individual wells can be found in Appendix A on the CD-ROM included with this volume. Dean DuBois of EnCana Oil and Gas (U.S.A.) Inc. reviewed and revised some of the data.