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Joseph R. Hatch

Publications and source records attributed to Joseph R. Hatch.

At least 19 recordsLinked to original sources
USGS2021

Geologic assessment of undiscovered oil and gas resources in the Cherokee Platform area of Kansas, Oklahoma, and Missouri

In 2015, the U.S. Geological Survey completed a geology-based assessment to estimate the volumes of undiscovered, technically recoverable petroleum resources in the Cherokee Platform Province area of southeastern Kansas, northeastern Oklahoma, and southwestern Missouri. The U.S. Geological Survey identified four stratigraphic intervals that contain petroleum source rocks: (1) thin shales in the Middle to Upper Ordovician Simpson Group, (2) shales within the Upper Devonian to Lower Mississippian Woodford Shale and stratigraphically equivalent Chattanooga Shale, (3) coals and coal-associated shales and mudstones in the Middle Pennsylvanian (Desmoinesian) Cherokee and Marmaton Groups, and (4) thin marine shales within the Marmaton Group and the Upper Pennsylvanian (Missourian) Kansas City and Lansing Groups. Based on the nature of the petroleum accumulations, the characterization of the compositions and thermal maturity of the organic matter in the rocks, and the compositions of the produced petroleum, the U.S. Geological Survey identified three total petroleum systems (TPS) containing four assessment units (AU): the Paleozoic Composite TPS with the Paleozoic Conventional Assessment Unit (AU), the Woodford/Chattanooga TPS with the Woodford Shale Oil AU and the Woodford Biogenic Gas AU, and the Desmoinesian Coal TPS with the Desmoinesian Coalbed Gas AU. Assessment unit summaries follow 1. Three source rock intervals have contributed geochemically distinct oils to reservoirs within the Paleozoic Conventional AU. These intervals are the Simpson Group; the Woodford and Chattanooga Shales; and the Marmaton, Kansas City, and Lansing Groups. The major petroleum source rocks are the Woodford and Chattanooga Shales. The Paleozoic Conventional AU includes reservoirs that range in age from the Upper Cambrian Arbuckle Group to the lower Permian Chase Group. Most oil production in the province has been from Pennsylvanian sandstone reservoirs. Estimated undiscovered petroleum resources for this AU are a mean of 3 million barrels of oil (MMBO), 140 billion cubic feet of gas (BCFG), and 4 million barrels of natural gas liquids (MMBNGL). 2. The Woodford Shale Oil AU contains undiscovered continuous petroleum resources within the Woodford Shale and Chattanooga Shale. The geologic model for the AU assumes that petroleum resources remain trapped within the shale following petroleum migration. For most of the AU, organic matter within the Woodford Shale and Chattanooga Shale is thermally mature with respect to petroleum generation as shown by vitrinite reflectance values between 0.6 and 1 percent. Petroleum has been produced from the Woodford Shale and Chattanooga Shale. Estimated undiscovered petroleum resources for this AU are means of 460 MMBO, 640 BCFG, and 7 MMBNGL. 3. The Woodford Shale Biogenic Gas AU contains undiscovered continuous petroleum resources in the east-central portion of the Cherokee Platform Province near the Ozark uplift where the Woodford Shale and Chattanooga Shale are at depths of 1,250 ft or shallower. At those depths, methanogenesis and(or) biodegradation of thermogenic natural gases can be found where the shale may be more fractured and more susceptible to groundwater penetrations. The mean assessed volume of undiscovered gas for this assessment unit is 416 BCFG and 1 MMBNGL. 4. The Desmoinesian Coalbed Gas AU contains undiscovered continuous petroleum resources within the Middle Pennsylvanian coals and coal-associated shales and mudstones. The boundaries for the Desmoinesian Coalbed Gas AU are, in part, defined by the extent, depth, and thickness of the coals. Within the Desmoinesian Coalbed Gas AU, a sweet spot area was delineated based on a 10 foot or greater net coal thickness. Gas analytical data show that natural gas produced from the coals has a mixed biogenic and thermogenic origin and that there is significant migration of natural gas into the coals from adjacent conventional sandstone reservoirs. The estimated mean volume of undiscovered gas is 10.0 trillion cubic ft of gas (TCFG), and 23 MMBNGL. For the three continuous (unconventional) assessment units and one conventional assessment unit in the Cherokee Platform Province, total mean volumes of undiscovered petroleum resources are estimated to be 463 MMBO, 11.2 TCFG and 35 MMBNGL.

Kansas, Missouri, Oklahoma↗
USGS2015

Geologic assessment of undiscovered oil and gas resources of the U.S. portion of the Michigan Basin

In 2004, the U.S. Geological Survey (USGS) completed an assessment of the undiscovered oil and gas potential of the U.S. portion of the Michigan Basin. For this assessment, the Michigan Basin includes most of the State of Michigan, as well as parts of Illinois, Indiana, Minnesota, Ohio, and Wisconsin. The assessment was based on the geologic elements of each of the six total petroleum systems defined in the basin, including (1) hydrocarbon source rocks (source-rock maturation and hydrocarbon generation and migration), (2) reservoir rocks (sequence stratigraphy and petrophysical properties), and (3) hydrocarbon traps (trap formation and timing). Using this geologic framework, the USGS estimated mean technically recoverable undiscovered continuous and conventional resources that total 990 million barrels of oil, 11.4 trillion cubic feet of natural gas, and 219 million barrels of natural gas liquids. Digital Data Series 69-T (DDS-69-T) is cataloged in the Pubs Warehouse as Data Series 69-T (DS-69-T).

Illinois, Indiana, Michigan, Minnesota, Ohio, Wisc↗
USGS2010

Coalbed methane resources of the Appalachian Basin, eastern USA

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.

Alabama, Georgia, Kentucky, Maryland, North Caroli↗
USGS2007

Geologic Assessment of Undiscovered Oil and Gas Resources of the Black Warrior Basin Province, Alabama and Mississippi

Introduction The purpose of the U.S. Geological Survey's (USGS) National Oil and Gas Assessment is to develop geologically based hypotheses regarding the potential for additions to oil and gas reserves in priority areas of the United States. The USGS recently completed an assessment of undiscovered oil and gas potential of the Cambrian-Ordovician carbonate rocks, the Chattanooga and Floyd Shales, and the Pottsville Formation coals in the Black Warrior Basin Province in northeastern Mississippi and northwestern Alabama in the Gulf Coast Region. The Cambrian-Ordovician carbonate rocks, the Chattanooga and Floyd Shales, and the Pottsville Formation coals are important because of their potential for natural gas resources. This assessment is based on geologic principles and uses the total petroleum system concept. The geologic elements of a total petroleum system include hydrocarbon source rocks (source rock maturation, hydrocarbon generation and migration), reservoir rocks (sequence stratigraphy and petrophysical properties), and hydrocarbon traps (trap formation and timing). The USGS used this geologic framework to define two total petroleum systems and three assessment units. All three assessment units were quantitatively assessed for undiscovered oil and gas resources.

Data Series↗
USGS2006

Chemical analyses of coal, coal-associated rocks and coal combustion products collected for the National Coal Quality Inventory

In 1999, the USGS initiated the National Coal Quality Inventory (NaCQI) project to address a need for quality information on coals that will be mined during the next 20-30 years. At the time this project was initiated, the publicly available USGS coal quality data was based on samples primarily collected and analyzed between 1973 and 1985. The primary objective of NaCQI was to create a database containing comprehensive, accurate and accessible chemical information on the quality of mined and prepared United States coals and their combustion byproducts. This objective was to be accomplished through maintaining the existing publicly available coal quality database, expanding the database through the acquisition of new samples from priority areas, and analysis of the samples using updated coal analytical chemistry procedures. Priorities for sampling include those areas where future sources of compliance coal are federally owned. This project was a cooperative effort between the U.S. Geological Survey (USGS), State geological surveys, universities, coal burning utilities, and the coal mining industry. Funding support came from the Electric Power Research Institute (EPRI) and the U.S. Department of Energy (DOE).

Open-File Report↗
USGS1999

Mechanical and thermal control of cleating and shearing in coal: examples from the Alabama coalbed methane field, USA

Natural fractures provide most of the interconnected macroporosity in coal. Therefore, understanding the characteristics of these fractures and the associated mechanisms of formation is essential for effective coalbed methane exploration and field management. Natural fractures in coal can be divided into two general types: cleat and shear structures. Cleat has been studied for more than a century, yet the mechanisms of cleat formation remain poorly understood (see reviews by Close, 1993; Laubach et al .,1998). An important aspect of cleating is that systematic fracturing of coal is takes place in concert with devolatization and concomitant shrinkage of the coal matrix during thermal maturation (Ammosov and Eremin, 1960). Coal, furthermore, is a mechanically weak rock type that is subject to bedding-plane shear between more competent beds like shale, sandstone, and limestone. Yet, the significance of shear structures in coal has only begun to attract scientific interest (Hathaway and Gayer, 1996; Pashin, 1998).

Alabama↗
USGS1998

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

Nearly 600 million bbl of oil (MMBO) and 1 to 1.5 trillion ft 3 (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 black shale (Utica and Antes shales) in the Appalachian basin. Moreover, 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 these 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 bitumen extract geochemistry identify the black 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. T max , 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 controlled by basement tectonics aided in the distribution of oil from the source to the trap. This fracture network permitted oil to move laterally and stratigraphically downsection through eastward-dipping, impermeable carbonate sequences to carrier zones such as the Middle Ordovician Knox unconformity, and to reservoirs such as porous dolomite in the Middle Ordovician Trenton Limestone in the Lima-Indiana field. Some of the oil and gas from the Utica-Antes source escaped vertically through a partially fractured, leaky Upper Ordovician shale seal into widespread Lower Silurian sandstone reservoirs.

Ohio, Ontario↗
USGS1992

Geology and mineral paragenesis of the Pea Ridge iron ore mine, Washington County, Missouri: Origin of the rare-earth-element- and gold-bearing breccia pipes. Some mineralogical and geochemical aspects of middle and upper Pennsylvanian marine black shales in part of the midcontinent region. Mineralogical and geochemical analysis of the metal- and organic-rich Grassy Creek Shale of the New Albany group (Upper Devonian and Lower Mississippian) in Hardin County, southern Illinois

No abstract available.

Illinois, Iowa, Kansas, Missouri, Nebraska, Oklaho↗
USGS1987

Possible Late Middle Ordovician organic carbon isotope excursion: Evidence from Ordovician oils and hydrocarbon source rocks, mid-continent and east-central United States

Oils generated by Middle Ordovician rocks are found throughout the Mid-Continent and east-central regions of the United States. Gas chromatographic characteristics of these oils include a relatively high abundance of n-alkanes with carbon numbers less than 20, a strong predominance of odd-numbered n-alkanes between C 10 and C 20 , and relatively small amounts of branched and cyclic alkanes. Saturated and aromatic hydrocarbon fractions of 43 Ordovician oils from the Anadarko, Ardmore, Forest City, Illinois, Michigan, Salina-Sedgwick, and Williston basins and the Iowa shelf demonstrate a wide range in carbon isotope composition (^dgr 13 C sat = -24.9 ^pmil to -33.9 ^pmil, (^dgr 13 C arom = -24.3 ^pmil to -33.7 ^pmil). Saturated and aromatic hydrocarbons extracted from late Middle Ordovician shales (17 core samples) show ranges in ^dgr 13 C similar to that of the oils. The wide ranges in ^dgr 13 C for oils and rock extracts reflect a major, positive excursion(s) (6-9 per ^pmil) in organic matter ^dgr 13 C in late Middle Ordovician rocks. This excursion has at least a regional significance in that it can be documented in sections 480 mi (770 km) apart in south-central Kansas and eastern Iowa. The distance may be as much as 930 mi (1,500 km) if the carbon isotope variations observed in Michigan basin Ordovician oils and in organic matter from late Middle Ordovician rocks in southwestern Ontario are related to the same carbon isotope excursion. Organic-matter ^dgr 13 C in core samples from south-central Kansas and eastern Iowa is not directly related to variations in quantity or quality of organic matter, or maceral compositi n. The positive excursion in organic matter ^dgr 13 C is a possible result of increased organic matter productivity and/or preservation. The parallel shifts in organic and carbonate ^dgr 13 C in core samples from 1 E. M. Greene well, Washington County, Iowa, imply changes in the isotope composition of the ocean-atmosphere carbon reservoir. Differences in the magnitude of the carbon isotope shifts between organic matter (8.8 ^pmil) and carbonate (4.2 ^pmil) in this core suggest a decrease, either locally or regionally, in available dissolved CO 2 , possibly a result of high organic-matter productivity and/or limited circulation in the late Middle Ordovician seas.

American Association of Petroleum Geologists Bulle↗
USGS1980

Chemical analyses of coal and coal-associated shale samples from the lower part of the Fort Union Formation, Little Snake River coal field, Sweetwater and Carbon counties, Wyoming

As part of a continuing program by the U.S. Geological Survey to collect and analyze representative samples of U.S. coals, 26 coal and 5 coal-associated shale samples were collected from 13 core and rotary-drill holes in the lower part of the Paleocene Fort Union Formation in the Little Snake River coal field, Sweetwater and Carbon Counties, Wyoming (fig. 1). The samples are briefly described in table 1. Twenty-six of the samples were collected from eight core holes that were drilled in connection with the Red Rim EMRIA (Energy Mineral Rehabilitation Inventory and Analyses) study (U.S. Department of the Interior, 1976). The locations of these eight holes and five other drill holes are shown in figure 2. Detailed geologic mapping of part of the sample collection area was done by Sanders (1974) in his work on the Riner quadrangle. Seven of the core holes (index map locations 1-7) are located in this quadrangle. In his discussion, Sanders (1974) describes the coal beds in the lower part of the Fort Union Formation as being thin, discontinuous, and generally lenticular. Few beds attain a thickness of more than five feet. In the Riner quadrangle coal beds in the lower part of the Fort Union Formation dip 12° to 24° northwestward.

Wyoming↗
USGS1979

Chemical analyses of coal from the Emery and Ferron Sandstone members of the Mancos Shale, Henry Mountains Field, Wayne and Garfield counties, Utah

As part of a continuing program by the U.S. Geological Survey to collect and chemically analyze representative samples of U.S. coals, 18 samples were collected from the Upper Cretaceous Emery and Ferron Sandstone Members of the Mancos Shale in the Henry Mountains coal field, Wayne and Garfield Counties, Utah (fig. 1). The 18 samples are briefly described in table 1. Thirteen of these samples were collected from seven holes that were drilled in connection with the Henry Mountains EMRIA (Energy Mineral Rehabilitation Inventory and Analyses) study (U.S. Department of the Interior, 1978). The locations of the seven core holes and the four other sampling sites are shown on figure 2. The Henry Mountains coal field is adjacent to the Henry Mountains of southeastern Utah. The basin is a long, narrow syncline about 110 km long and 24 km wide bounded on the west by the Waterpocket Fold and on the east by the Henry Mountains. The most comprehensive geologic report available on the area is by Hunt and others (1953). Their work included a considerable amount of information on the coal resources. Other work in the area concerning coal or stratigraphy of coal bearing units includes: Doelling (1972), Peterson and Ryder (1975), Doelling (1975), Law (1977; 1978; 1979 a,b), and U.S. Department of the Interior (1978). In the Henry Mountains field, there are three coal bearing units in rocks of Late Cretaceous age. In ascending order they are the Dakota Sandstone, the Ferron Sandstone Member of the Mancos Shale, and the Emery Sandstone Member of the Mancos Shale. The coal beds of the Henry Mountains coal field originated as layers of peat that were deposited, for the most part, in coastal swamp environments. Individual coal beds are discontinuous and exhibit large variations in thickness and quality. The thickest and most continuous coal beds occur in the Emery Sandstone Member along or near the axis of the Henry Mountains syncline (Law, 1978).

Utah↗
USGS1979

Chemical analyses of coal and coal-associated rock samples from the Rosebud and McKay coal beds, Tongue River Member of the Fort Union Formation, Colstrip coal deposit, Rosebud County, Montana

As part of a continuing program by the U.S. Geological Survey to collect and chemically analyze representative samples of U.S. coals, 61 coal and coal-associated rock samples were collected from the Rosebud and McKay beds in the Paleocene Tongue River Member of the Fort Union Formation in Rosebud County, Montana. This area is located in the Montana part of the Powder River region, specifically within the Coistrip coal deposit as defined by Matson and Blumer, 1974. Forty of the samples (36 coal and 4 coal-associated rock) are from the Rosebud bed and 21 samples (all coal) are from the McKay bed. The McKay bed is between 5.5 and 18.6 m. below the Rosebud bed. The samples were collected from the Big Sky Mine and from 13 core holes in sec. 1, 2, and 27, T. 1 N., R. 41 E.; sec. 23 and 35, T. 2 N., R. 41 E.; and in sec. 1, 3, 5, 9, 15, and 16, T. 1 N., R. 40 E. The location of the sample collection area is shown in figure 1. Brief descriptions of all 61 samples are listed in table 1 and locations of sampling sites are shown in figure 2. Estimated strippable coal resources for the Rosebud bed in this area exceed 1,305 metric tons (1,439 million short tons) (Matson and Blumer, 1974). There are currently no estimates of coal resources for the McKay bed from this area. Analyses of samples D172034 through D172051 have previously been published in Swanson and others (1976) and are included here in order to provide a more complete data listing. For additional information on sulfur and trace element contents in the Rosebud and McKay coal beds, see Chadwick, Woodriff and others (1975) and Chadwick, Rice and others (1975).

Montana↗