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1

Marcellus Shale Educational Webinar Series  

E-Print Network [OSTI]

#12;Marcellus Shale Litigation and Legislation December 17, 2009 7 . Pennsylvania Oil and Gas Law1 Marcellus Shale Educational Webinar Series October 2009 - March 2010 Penn State Cooperative Extension #12;2 Marcellus Shale Webinar Series Planning Committee · Members ­ Mark Douglass, Jefferson

Boyer, Elizabeth W.

2

Geochemical and Strontium Isotope Characterization of Produced Waters from Marcellus Shale Natural Gas Extraction  

SciTech Connect (OSTI)

Extraction of natural gas by hydraulic fracturing of the Middle Devonian Marcellus Shale, a major gas-bearing unit in the Appalachian Basin, results in significant quantities of produced water containing high total dissolved solids (TDS). We carried out a strontium (Sr) isotope investigation to determine the utility of Sr isotopes in identifying and quantifying the interaction of Marcellus Formation produced waters with other waters in the Appalachian Basin in the event of an accidental release, and to provide information about the source of the dissolved solids. Strontium isotopic ratios of Marcellus produced waters collected over a geographic range of ?375 km from southwestern to northeastern Pennsylvania define a relatively narrow set of values (?Sr SW = +13.8 to +41.6, where ?Sr SW is the deviation of the 87Sr/86Sr ratio from that of seawater in parts per 104); this isotopic range falls above that of Middle Devonian seawater, and is distinct from most western Pennsylvania acid mine drainage and Upper Devonian Venango Group oil and gas brines. The uniformity of the isotope ratios suggests a basin-wide source of dissolved solids with a component that is more radiogenic than seawater. Mixing models indicate that Sr isotope ratios can be used to sensitively differentiate between Marcellus Formation produced water and other potential sources of TDS into ground or surface waters.

Elizabeth C. Chapman, Rosemary C. Capo, Brian W. Stewart,*, Carl S. Kirby, Richard W. Hammack,

2012-02-24T23:59:59.000Z

3

Geochemical and Strontium Isotope Characterization of Produced Waters from Marcellus Shale Natural Gas Extraction  

SciTech Connect (OSTI)

Extraction of natural gas by hydraulic fracturing of the Middle Devonian Marcellus Shale, a major gas-bearing unit in the Appalachian Basin, results in significant quantities of produced water containing high total dissolved solids (TDS). We carried out a strontium (Sr) isotope investigation to determine the utility of Sr isotopes in identifying and quantifying the interaction of Marcellus Formation produced waters with other waters in the Appalachian Basin in the event of an accidental release, and to provide information about the source of the dissolved solids. Strontium isotopic ratios of Marcellus produced waters collected over a geographic range of 375 km from southwestern to northeastern Pennsylvania define a relatively narrow set of values (?{sub Sr}{sup SW} = +13.8 to +41.6, where ?{sub Sr}{sup SW} is the deviation of the {sup 87}Sr/{sup 86}Sr ratio from that of seawater in parts per 10{sup 4}); this isotopic range falls above that of Middle Devonian seawater, and is distinct from most western Pennsylvania acid mine drainage and Upper Devonian Venango Group oil and gas brines. The uniformity of the isotope ratios suggests a basin-wide source of dissolved solids with a component that is more radiogenic than seawater. Mixing models indicate that Sr isotope ratios can be used to sensitively differentiate between Marcellus Formation produced water and other potential sources of TDS into ground or surface waters.

Chapman, Elizabeth C; Capo, Rosemary C.; Stewart, Brian W.; Kirby, Carl S.; Hammack, Richard W.; Schroeder, Karl T.; Edenborn, Harry M.

2012-03-20T23:59:59.000Z

4

Utica, Kentucky: Energy Resources | Open Energy Information  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data CenterFranconia, Virginia:FAQ < RAPID Jump to:Seadov PtyInformation UC 19-6-401UpsonUtah StateLoading map...Utica, Kentucky: Energy

5

Utica, Mississippi: Energy Resources | Open Energy Information  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data CenterFranconia, Virginia:FAQ < RAPID Jump to:Seadov PtyInformation UC 19-6-401UpsonUtah StateLoading map...Utica, Kentucky:

6

Utica, Ohio: Energy Resources | Open Energy Information  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data CenterFranconia, Virginia:FAQ < RAPID Jump to:Seadov PtyInformation UC 19-6-401UpsonUtah StateLoading map...Utica,

7

Utica, Wisconsin: Energy Resources | Open Energy Information  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data CenterFranconia, Virginia:FAQ < RAPID Jump to:Seadov PtyInformation UC 19-6-401UpsonUtah StateLoading map...Utica,9655569°,

8

Energy Transitions: A Systems Approach Including Marcellus Shale Gas Development  

E-Print Network [OSTI]

Energy Transitions: A Systems Approach Including Marcellus Shale Gas Development A Report Transitions: A Systems Approach Including Marcellus Shale Gas Development Executive Summary In the 21st the Marcellus shale In addition to the specific questions identified for the case of Marcellus shale gas in New

Angenent, Lars T.

9

Focus on the Marcellus Shale By Lisa Sumi  

E-Print Network [OSTI]

Shale Gas: Focus on the Marcellus Shale By Lisa Sumi FOR THE OIL & GAS ACCOUNTABILITY PROJECT on potential oil and gas development in the Marcellus Shale formation in northeastern Pennsylvania · www.ogap.org #12;Shale Gas: Focus on the Marcellus Shale A REPORT COMPILED FOR THE OIL AND GAS

Boyer, Elizabeth W.

10

Modular CHP System for Utica College: Design Specification, March 2007 |  

Energy Savers [EERE]

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Office of Inspector General Office0-72.pdfGeorgeDoesn't32Department of Energy Modular CHP System for Utica College:

11

Pennsylvania Energy Impacts Assessment Report 1: Marcellus Shale Natural Gas and Wind  

E-Print Network [OSTI]

Pennsylvania Energy Impacts Assessment Report 1: Marcellus Shale Natural Gas and Wind #12;1 Pennsylvania Energy Impacts Assessment Report 1: Marcellus Shale Natural Gas and Wind November 15, 2010 Author.....................................................................................................................3 Marcellus Shale Natural Gas

Boyer, Elizabeth W.

12

Launching a Cornell Examination of the Marcellus System The issues related to the development of the Marcellus Shale unconventional gas resource are  

E-Print Network [OSTI]

of the Marcellus Shale unconventional gas resource are emblematic of a whole family of extremely complicated Energy. The development plans for the Marcellus Shale are unfolding immediately in our backyards and require of different ways of developing the Marcellus Shale and the economics of not developing the Marcellus Shale. We

Angenent, Lars T.

13

Development of the Natural Gas Resources in the Marcellus Shale  

E-Print Network [OSTI]

Development of the Natural Gas Resources in the Marcellus Shale New York, Pennsylvania, Virginia for informational purposes only and does not support or oppose development of the Marcellus Shale natural gas information regarding shale gas well development, ancillary facilities asso- ciated with that development

Boyer, Elizabeth W.

14

The Public Health Implications of Marcellus Shale Activities  

E-Print Network [OSTI]

INCIDENT #12;#12;#12;Implications of the Gulf Oil Spill to Marcellus Shale Activities - EnvironmentalThe Public Health Implications of Marcellus Shale Activities Bernard D. Goldstein, MD Department using Data.FracTracker.org. #12;Drilling Rig in Rural Upshur County, WV Source: WVSORO, Modern Shale Gas

Jiang, Huiqiang

15

Intergrated study of the Devonian-age black shales in eastern Ohio. Final report  

SciTech Connect (OSTI)

This integrated study of the Devonian-age shales in eastern Ohio by the Ohio Department of Natural Resources, Division of Geological Survey is part of the Eastern Gas Shales Project sponsored by the US Department of Energy. The six areas of research included in the study are: (1) detailed stratigraphic mapping, (2) detailed structure mapping, (3) mineralogic and petrographic characterization, (4) geochemical characterization, (5) fracture trace and lineament analysis, and (6) a gas-show monitoring program. The data generated by the study provide a basis for assessing the most promising stratigraphic horizons for occurrences of natural gas within the Devonian shale sequence and the most favorable geographic areas of the state for natural gas exploration and should be useful in the planning and design of production-stimulation techniques. Four major radioactive units in the Devonian shale sequence are believed to be important source rocks and reservoir beds for natural gas. In order of potential for development as an unconventional gas resource, they are (1) lower and upper radioactive facies of the Huron Shale Member of the Ohio Shale, (2) upper Olentangy Shale (Rhinestreet facies equivalent), (3) Cleveland Shale Member of the Ohio Shale, and (4) lower Olentangy Shale (Marcellus facies equivalent). These primary exploration targets are recommended on the basis of areal distribution, net thickness of radioactive shale, shows of natural gas, and drilling depth to the radioactive unit. Fracture trends indicate prospective areas for Devonian shale reservoirs. Good geological prospects in the Devonian shales should be located where the fracture trends coincide with thick sequences of organic-rich highly radioactive shale.

Gray, J.D.; Struble, R.A.; Carlton, R.W.; Hodges, D.A.; Honeycutt, F.M.; Kingsbury, R.H.; Knapp, N.F.; Majchszak, F.L.; Stith, D.A.

1982-09-01T23:59:59.000Z

16

Potential Economic Impacts of Marcellus Shale in Pennsylvania: Reflections on the Perryman Group Analysis from Texas  

E-Print Network [OSTI]

Potential Economic Impacts of Marcellus Shale in Pennsylvania: Reflections on the Perryman Group The exploration and development of the Marcellus Shale natural gas play has significant potential to affect in the Barnett Shale region of north Texas. The Barnett Shale play is very similar in geology to the Marcellus

Boyer, Elizabeth W.

17

Life Cycle Analysis on Greenhouse Gas (GHG) Emissions of Marcellus Shale Gas Supporting Information  

E-Print Network [OSTI]

Life Cycle Analysis on Greenhouse Gas (GHG) Emissions of Marcellus Shale Gas Supporting Information 1. GHG Emissions Estimation for Production of Marcellus Shale Gas 1.1 Preparation of Well Pad estimate from Columbia University shows the size of a multi-well pad of Marcellus Shale averages 20

Jaramillo, Paulina

18

Potential Health Effects of Marcellus Shale Activities: The Need for Public  

E-Print Network [OSTI]

. #12;Implications of the Gulf Oil Spill to Marcellus Shale Activities - Environmental and human health salt (Proprietary) 10.0 - 30.0% #12;Implications of the Gulf Oil Spill to Marcellus Shale ActivitiesPotential Health Effects of Marcellus Shale Activities: The Need for Public Health Surveillance

Sibille, Etienne

19

Methane adsorption on Devonian shales  

E-Print Network [OSTI]

METHANE ADSORPTION ON DEVONIAN SHALES A Thesis by FAN-CHANG LI Submitted to thc Office of Graclua4e Sturiics of texas AgiM Ulllvel'sliy in pari, ial fulfilhuent of t, hc requirements I'or t, hc degree of ii IAS'I'Elf OF SCIL'NCE December... 1992 Major Subject, : Chemical Engineering METHANE ADSORPTION ON DEVONIAN SHALES A Thesis l&y I'AN-CHANC LI Approved as to style and contcut by: A. T. 'vtratson (Chair of Commitl. ee) John C. Slattery (Member) Bruce . Hcrhcrt (Memhcr...

Li, Fan-Chang

1992-01-01T23:59:59.000Z

20

Subcontract Report: Modular Combined Heat & Power System for Utica College: Design Specification  

SciTech Connect (OSTI)

Utica College, located in Utica New York, intends to install an on-site power/cogeneration facility. The energy facility is to be factory pre-assembled, or pre- assembled in modules, to the fullest extent possible, and ready to install and interconnect at the College with minimal time and engineering needs. External connections will be limited to fuel supply, electrical output, potable makeup water as required and cooling and heat recovery systems. The proposed facility will consist of 4 self-contained, modular Cummins 330kW engine generators with heat recovery systems and the only external connections will be fuel supply, electrical outputs and cooling and heat recovery systems. This project was eventually cancelled due to changing DOE budget priorities, but the project engineers produced this system design specification in hopes that it may be useful in future endeavors.

Rouse, Greg [Gas Technology Institute

2007-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


21

Energy Transitions: A Systems Approach Including Marcellus Shale Gas Development  

E-Print Network [OSTI]

Energy Transitions: A Systems Approach Including Marcellus Shale Gas Development A Report Engineering) W. VA #12;Energy Transitions: A Systems Approach August 2011 version Page 2 Energy Transitions sources globally, some very strong short-term drivers of energy transitions reflect rising concerns over

Walter, M.Todd

22

SPE-163690-MS Synthetic, Geomechanical Logs for Marcellus Shale  

E-Print Network [OSTI]

SPE-163690-MS Synthetic, Geomechanical Logs for Marcellus Shale M. O. Eshkalak, SPE, S. D of hydrocarbons from the reservoirs, notably shale, is attributed to realizing the key fundamentals of reservoir and mineralogy is crucial in order to identify the "right" pay-zone intervals for shale gas production. Also

Mohaghegh, Shahab

23

Effects of diagenesis on the Nd-isotopic composition of black shales from the 420 Ma Utica Shale Magnafacies  

E-Print Network [OSTI]

-isotopic ratios were measured in whole rock black shales with different grades of thermal maturity from the Utica/Sm that cannot be explained solely by diagenesis, implying source heterogeneity. Whole rock black shales maturation), which alters the Sm/Nd ratio of the rock, it can be argued that the different components

Basu, Asish R.

24

Department of Mechanical Engineering Fall 2010 Geothermal Pressure Reduction Marcellus Shale Production  

E-Print Network [OSTI]

Shale Production Overview (problem and challenges) During the preliminary production stage, Marcellus Shale natural gas wells have a wellhead pressure that exceeds the material limits of typical above understanding of Marcellus Shale natural gas wells and drilling was gathered on-site. Evaluation of (5

Demirel, Melik C.

25

A Comparative Study of the Mississippian Barnett Shale, Fort Worth Basin, and Devonian Marcellus Shale, Appalachian Basin  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr May JunDatastreamsmmcrcalgovInstrumentsrucLasDelivered‰PNGExperience hands-onASTROPHYSICSHe β- DecayBenew20-Year6APlasma APast andA

26

Extracting the economic benefits of natural resources in the Marcellus Shale Region  

E-Print Network [OSTI]

My thesis seeks to explore the challenge of value capture from natural resources using the case of the Marcellus Shale in West Virginia and Pennsylvania as an exemplar. I examine the mechanisms in place to capture the ...

Hess, Sara Lynn

2014-01-01T23:59:59.000Z

27

Life cycle greenhouse gas emissions of Marcellus shale gas This article has been downloaded from IOPscience. Please scroll down to see the full text article.  

E-Print Network [OSTI]

Life cycle greenhouse gas emissions of Marcellus shale gas This article has been downloaded from.1088/1748-9326/6/3/034014 Life cycle greenhouse gas emissions of Marcellus shale gas Mohan Jiang1 , W Michael Griffin2,3 , Chris greenhouse gas (GHG) emissions from the production of Marcellus shale natural gas and compares its emissions

Jaramillo, Paulina

28

Economic Impacts of Marcellus Shale in Pennsylvania: Employment and Income in 2009 2011 Penn State Extension and Penn College www.msetc.org 1  

E-Print Network [OSTI]

Economic Impacts of Marcellus Shale in Pennsylvania: Employment and Income in 2009 ©2011 Penn State Extension and Penn College www.msetc.org 1 Economic Impacts of Marcellus Shale in Pennsylvania: Employment and Income in 2009 August 2011 www.msetc.org The Marcellus Shale Education & Training Center (MSETC

Boyer, Elizabeth W.

29

Geologic analysis of Devonian Shale cores  

SciTech Connect (OSTI)

Cleveland Cliffs Iron Company was awarded a DOE contract in December 1977 for field retrieval and laboratory analysis of cores from the Devonian shales of the following eleven states: Michigan, Illinois, Indiana, Ohio, New York, Pennsylvania, West Virginia, Maryland, Kentucky, Tennessee and Virginia. The purpose of this project is to explore these areas to determine the amount of natural gas being produced from the Devonian shales. The physical properties testing of the rock specimens were performed under subcontract at Michigan Technological University (MTU). The study also included LANDSAT information, geochemical research, structural sedimentary and tectonic data. Following the introduction, and background of the project this report covers the following: field retrieval procedures; laboratory procedures; geologic analysis (by state); references and appendices. (ATT)

none,

1982-02-01T23:59:59.000Z

30

Reservoir and stimulation analysis of a Devonian Shale gas field  

E-Print Network [OSTI]

. The Gas Research Institute (GRI) which sponsored this work under GRI Contract No. 5084-213-0980, "Analysis of Eastern Devonian Gas Shales Production Data;" 2. Doug Terry and Joe Petty with Union Drilling, Inc. who showed great interest in this study... and enhance productivity. ~St h The Devonian Shales in the Mason County Field study area can be subdivided using gamma ray logs as follows (in descending order): Upper Devonian Undivided, Huron Shale Member of the Ohio Shale, Java Formation, Angola Shale...

Shaw, James Stanley

1986-01-01T23:59:59.000Z

31

Private Water Well Testing in Areas Impacted by Marcellus Shale Gas Drilling  

E-Print Network [OSTI]

Private Water Well Testing in Areas Impacted by Marcellus Shale Gas Drilling (Updated November 15th in the absence of shale-gas drilling, well owners are strongly encouraged to evaluate their water on a regular review of shale gas drilling in New York State, as well as the most comprehensive collection of data

Manning, Sturt

32

Geochemical evidence for possible natural migration of Marcellus Formation brine to  

E-Print Network [OSTI]

as the potential for contamination from toxic substances in hydraulic fracturing fluid and/or pro- duced brinesGeochemical evidence for possible natural migration of Marcellus Formation brine to shallow of stray gas, metal-rich formation brines, and hydrau- lic fracturing and/or flowback fluids to drinking

33

New York Marcellus Shale: Industry boom put on hold  

SciTech Connect (OSTI)

Key catalysts for Marcellus Shale drilling in New York were identified. New York remains the only state in the nation with a legislative moratorium on high-volume hydraulic fracturing, as regulators and state lawmakers work to balance the advantages of potential economic benefits while protecting public drinking water resources and the environment. New York is being particularly careful to work on implementing sufficiently strict regulations to mitigate the environmental impacts Pennsylvania has already seen, such as methane gas releases, fracturing fluid releases, flowback water and brine controls, and total dissolved solids discharges. In addition to economic and environmental lessons learned, the New York Department of Environmental Conservation (DEC) also acknowledges impacts to housing markets, security, and other local issues, and may impose stringent measures to mitigate potential risks to local communities. Despite the moratorium, New York has the opportunity to take advantage of increased capital investment, tax revenue generation, and job creation opportunities by increasing shale gas activity. The combination of economic benefits, industry pressure, and recent technological advances will drive the pursuit of natural gas drilling in New York. We identify four principal catalysts as follows: Catalyst 1: Pressure from Within the State. Although high-volume hydraulic fracturing has become a nationally controversial technology, shale fracturing activity is common in every U.S. state except New York. The regulatory process has delayed potential economic opportunities for state and local economies, as well as many industry stakeholders. In 2010, shale gas production accounted for $18.6 billion in federal royalty and local, state, and federal tax revenues. (1) This is expected to continue to grow substantially. The DEC is under increased pressure to open the state to the same opportunities that Alabama, Arkansas, California, Colorado, Kansas, Louisiana, Montana, New Mexico, North Dakota, Ohio, Oklahoma, Pennsylvania, South Dakota, Texas, Utah, West Virginia, and Wyoming are pursuing. Positive labor market impacts are another major economic draw. According to the Revised Draft SGEIS on the Oil, Gas and Solution Mining Regulatory Program (September 2011), hydraulic fracturing would create between 4,408 and 17,634 full-time equivalent (FTE) direct construction jobs in New York State. Indirect employment in other sectors would add an additional 29,174 FTE jobs. Furthermore, the SGEIS analysis suggests that drilling activities could add an estimated $621.9 million to $2.5 billion in employee earnings (direct and indirect) per year, depending upon how much of the shale is developed. The state would also receive direct tax receipts from leasing land, and has the potential to see an increase in generated indirect revenue. Estimates range from $31 million to $125 million per year in personal income tax receipts, and local governments would benefit from revenue sharing. Some landowner groups say the continued delay in drilling is costing tens of thousands of jobs and millions of dollars in growth for New York, especially in the economically stunted upstate. A number of New York counties near Pennsylvania, such as Chemung, NY, have experienced economic uptick from Pennsylvania drilling activity just across the border. Chemung officials reported that approximately 1,300 county residents are currently employed by the drilling industry in Pennsylvania. The Marcellus shale boom is expected to continue over the next decade and beyond. By 2015, gas drilling activity could bring 20,000 jobs to New York State alone. Other states, such as Pennsylvania and West Virginia, are also expected to see a significant increase in the number of jobs. Catalyst 2: Political Reality of the Moratorium. Oil and gas drilling has taken place in New York since the 19th century, and it remains an important industry with more than 13,000 currently active wells. The use of hydraulic fracturing in particular has been employed for decades. Yet, as technological

Mercurio, Angelique

2012-01-16T23:59:59.000Z

34

Update on the aquifer/wetlands restoration project at Utica, Nebraska, with recommendations for remapping of the carbon tetrachloride contamination in groundwater.  

SciTech Connect (OSTI)

In 1992-1993, Argonne National Laboratory investigated potential carbon tetrachloride contamination that might be linked to the former grain storage facility operated by the Commodity Credit Corporation (CCC) of the U.S. Department of Agriculture (USDA) at Utica, Nebraska. These initial studies identified carbon tetrachloride in a plume of contaminated groundwater, extending approximately 3,500 ft southeastward from the former CCC/USDA facility, within a shallow upper aquifer that had been used previously as a municipal water source by the town (Figure 1.1). A deeper aquifer used as the current municipal water source was found to be free of carbon tetrachloride contamination. Although the shallow aquifer was no longer being used as a source of drinking water at Utica, additional studies indicated that the carbon tetrachloride could pose an unacceptable health threat to potential future residents who might install private wells along the expected downgradient migration pathway of the plume. On the basis of these findings, corrective action was recommended to decrease the carbon tetrachloride concentrations in the upper aquifer to acceptable levels (Argonne 1993a,b, 1995). Initial discussions with the Utica village board indicated that any restoration strategies involving nonbeneficial discharge of treated groundwater in the immediate vicinity of Utica would be unacceptable to the town. To address this concern, the CCC/USDA and Argonne, in cooperation with multiple federal and state regulatory and environmental agencies (Table 1.1) proposed a treatment strategy for the Utica groundwater employing groundwater extraction coupled with the seasonal use of agricultural spray irrigation equipment to simultaneously (1) remove carbon tetrachloride from the groundwater (by volatilization to the atmosphere) and (2) discharge the treated groundwater to enhance the development of wetlands in the North Lake Basin Wildlife Management Area, just north of the town (Argonne 2000). To develop this treatment approach, additional groundwater sampling was conducted to update the distribution of carbon tetrachloride in groundwater identified in the preliminary studies in 1992-1993. In March 1998, detailed mapping of the carbon tetrachloride plume was performed by using the Argonne cone penetrometer (CPT) vehicle to collect groundwater samples for analyses for volatile organic compounds (VOCs) at 13 locations (PS01-PS09, PS12, PS16, PS17, PS19; Figure 1.2). The samples were collected in vertical profiles through the aquifer, at 10-ft intervals. The results of this 1998 study (Table 1.2) demonstrated that the three-dimensional distribution of carbon tetrachloride in the aquifer is complex, with multiple 'hot spots' occurring in the plume at various depths and distances along its length (Argonne 2000). In October 2002, the CCC/USDA requested that Argonne perform targeted groundwater sampling at Utica to document the migration of the carbon tetrachloride plume since the 1998 sampling event. In February 2003, vertical-profile groundwater sampling for VOCs analyses was conducted at 8 selected locations (PS01, PS04-PS07, PS12, PS19, PS20; Figure 1.2 and Table 1.3). The lateral and vertical configuration of the carbon tetrachloride plume, as identified in the 2003 study (Argonne 2003), is illustrated in Figures 1.3-1.7. On the basis of the 2003 groundwater sampling results, a remedial system employing four extraction wells (GWEX 1-GWEX 4), with groundwater treatment by spray irrigation and conventional air stripping, was implemented at Utica, with the concurrence of the CCC/USDA and the agencies identified in Table 1.1. The principal components of the Utica system (shown in Figure 1.8) are described briefly in Section 1.2. Operation of well GWEX4 and the associated air stripper began on October 29, 2004, and routine operation of wells GWEX1-GWEX3 and the spray irrigation treatment units began on November 22, 2004.

LaFreniere, L. M.; Environmental Science Division

2010-04-20T23:59:59.000Z

35

Summary of operations and performance of the Utica aquifer and North Lake Basin Wetlands restoration project in December 2006-November 2007.  

SciTech Connect (OSTI)

This document summarizes the performance of the groundwater restoration systems installed by the Commodity Credit Corporation of the U.S. Department of Agriculture (CCC/USDA) at the former CCC/USDA grain storage facility in Utica, Nebraska, during the third year of system operation, from December 1, 2006, until November 30, 2007. In the project at Utica, the CCC/USDA is cooperating with multiple state and federal agencies to remove carbon tetrachloride contamination from a shallow aquifer underlying the town and to provide supplemental treated groundwater for use in the restoration of a nearby wetlands area. Argonne National Laboratory has assisted the CCC/USDA by providing technical oversight for the aquifer restoration effort and facilities during this review period. This document presents overviews of the aquifer restoration facilities (Section 2) and system operations (Section 3), then describes groundwater production results (Section 4); groundwater treatment results (Section 5); and associated groundwater monitoring, system modifications, and costs during the review period (Section 6). Section 7 summarizes the present year of operation and provides some comparisons with system performance in previous years. The performance of the groundwater restoration systems at Utica in earlier years was summarized in greater detail previously (Argonne 2005, 2006).

LaFreniere, L. M.; Environmental Science Division

2008-04-02T23:59:59.000Z

36

An Integrated Water Treatment Technology Solution for Sustainable Water Resource Management in the Marcellus Shale  

SciTech Connect (OSTI)

This Final Scientific/ Technical Report submitted with respect to Project DE-FE0000833 titled 'An Integrated Water Treatment Technology Solution for Sustainable Water Resource Management in the Marcellus Shale' in support of final reporting requirements. This final report contains a compilation of previous reports with the most current data in order to produce one final complete document. The goal of this research was to provide an integrated approach aimed at addressing the increasing water resource challenges between natural gas production and other water stakeholders in shale gas basins. The objective was to demonstrate that the AltelaRain{reg_sign} technology could be successfully deployed in the Marcellus Shale Basin to treat frac flow-back water. That objective has been successfully met.

Matthew Bruff; Ned Godshall; Karen Evans

2011-04-30T23:59:59.000Z

37

Speaker to Address Impact of Natural Gas Production on Greenhouse Gas Emissions When used for power generation, Marcellus Shale natural gas can significantly reduce carbon  

E-Print Network [OSTI]

generation, Marcellus Shale natural gas can significantly reduce carbon dioxide emissions, but questions have been raised whether development of shale gas resources results in an overall lower greenhouse gas, "Life Cycle Greenhouse Gas Emissions of Marcellus Shale Gas," appeared in Environmental Research Letters

Boyer, Elizabeth W.

38

Devonian shale gas resource assessment, Illinois basin  

SciTech Connect (OSTI)

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.

Cluff, R.M.; Cluff, S.G.; Murphy, C.M. [Discovery Group, Inc., Denver, CO (United States)

1996-12-31T23:59:59.000Z

39

Devonian shale gas resource assessment, Illinois basin  

SciTech Connect (OSTI)

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.

Cluff, R.M.; Cluff, S.G.; Murphy, C.M. (Discovery Group, Inc., Denver, CO (United States))

1996-01-01T23:59:59.000Z

40

Summary of first-year operations and performance of the Utica Aquifer and North Lake Basin Wetlands Restoration Project in October 2004-November 2005.  

SciTech Connect (OSTI)

This document summarizes the performance of the groundwater restoration systems installed by the Commodity Credit Corporation of the U.S. Department of Agriculture (CCC/USDA) at the former CCC/USDA grain storage facility in Utica, Nebraska, during the initial period of system operation, from October 29, 2004, until November 31, 2005. In the project at Utica, the CCC/USDA is cooperating with multiple state and federal agencies to remove carbon tetrachloride contamination from a shallow aquifer underlying the town and to provide supplemental treated groundwater for use in the restoration of a nearby wetlands area. Argonne National Laboratory has assisted the CCC/USDA by providing technical oversight for the aquifer restoration effort and facilities during this review period. This document presents overviews of the aquifer restoration facilities (Section 2) and system operations (Section 3), then describes groundwater production results (Section 4), groundwater treatment results (Section 5), and modifications and costs during the review period (Section 6). Section 7 summarizes the first year of operation.

LaFreniere, L. M.; Sedivy, R. A.

2006-01-27T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


41

Five-year summary and evaluation of operations and performance of the Utica aquifer and North Lake Basin Wetlands restoration project in 2004-2009.  

SciTech Connect (OSTI)

This document reviews the performance of the groundwater (and wetlands) restoration program implemented by the Commodity Credit Corporation of the U.S. Department of Agriculture (CCC/USDA) at the former CCC/USDA grain storage facility in Utica, Nebraska, during the first five years (2004-2009) of this initiative. The report summarizes treatment system operational data and regulatory compliance monitoring results for the site during this period, together with the results of the targeted groundwater sampling and analysis for volatile organic compounds (VOCs) conducted in early 2010 (following completion of the fifth year of systems operation), to assess the initial five years of progress of the Utica remediation effort. On the basis of the 2003 groundwater sampling results, a remedial system employing 4 extraction wells (GWEX1-GWEX4), with groundwater treatment by spray irrigation and conventional air stripping, was implemented with the concurrence of the CCC/USDA and the agencies (Table 1.1). The principal components of the system are shown in Figure 1.3 and are briefly described in Section 1.2. Operation of well GWEX4 and the associated air stripper began on October 29, 2004, and routine operation of wells GWEX1-GWEX3 and the spray irrigation treatment units began on November 22, 2004.

LaFreniere, L. M. (Environmental Science Division) [Environmental Science Division

2011-09-13T23:59:59.000Z

42

Summary of operations and performance of the Utica aquifer and North Lake Basin wetlands restoration project in December 2005-November 2006.  

SciTech Connect (OSTI)

This document summarizes the performance of the groundwater restoration systems installed by the Commodity Credit Corporation of the U.S. Department of Agriculture (CCC/USDA) at the former CCC/USDA grain storage facility in Utica, Nebraska, during the second year of system operation, from December 1, 2005, until November 31, 2006. In the project at Utica, the CCC/USDA is cooperating with multiple state and federal agencies to remove carbon tetrachloride contamination from a shallow aquifer underlying the town and to provide supplemental treated groundwater for use in the restoration of a nearby wetlands area. Argonne National Laboratory has assisted the CCC/USDA by providing technical oversight for the aquifer restoration effort and facilities during this review period. This document presents overviews of the aquifer restoration facilities (Section 2) and system operations (Section 3), then describes groundwater production results (Section 4), groundwater treatment results (Section 5), and associated groundwater monitoring, system modifications, and costs during the review period (Section 6). Section 7 summarizes the present year of operation.

LaFreniere, L. M.; Environmental Science Division

2006-12-21T23:59:59.000Z

43

Summary of operations and performance of the Utica aquifer and North Lake Basin Wetlands restoration project in December 2007-November 2008.  

SciTech Connect (OSTI)

This document summarizes the performance of the groundwater restoration systems installed by the Commodity Credit Corporation of the U.S. Department of Agriculture (CCC/USDA) at the former CCC/USDA grain storage facility in Utica, Nebraska, during the fourth year of system operation, from December 1, 2007, until November 30, 2008. Performance in earlier years was reported previously (Argonne 2005, 2006, 2008). In the project at Utica, the CCC/USDA is cooperating with multiple state and federal agencies to remove carbon tetrachloride contamination from a shallow aquifer underlying the town and to provide supplemental treated groundwater for use in the restoration of a nearby wetlands area. Argonne National Laboratory assisted the CCC/USDA by providing technical oversight for the aquifer restoration effort and facilities during this review period. This document presents overviews of the aquifer restoration facilities (Section 2) and system operations (Section 3). The report then describes groundwater production results (Section 4); groundwater treatment results (Section 5); and associated maintenance, system modifications, and costs during the review period (Section 6). Section 7 summarizes the present year of operation.

LaFreniere, L. M.; Sedivy, R. A.; Environmental Science Division

2009-01-23T23:59:59.000Z

44

Summary of operations and performance of the Utica aquifer and North Lake Basin Wetlands restoration project in December 2009-November 2010.  

SciTech Connect (OSTI)

This document summarizes the performance of the groundwater restoration systems installed by the Commodity Credit Corporation of the U.S. Department of Agriculture (CCC/USDA) at the former CCC/USDA grain storage facility in Utica, Nebraska, during the sixth year of system operation, from December 1, 2009, until November 30, 2010. In the project at Utica, the CCC/USDA is cooperating with multiple state and federal agencies to remove carbon tetrachloride contamination from a shallow aquifer underlying the town and to provide supplemental treated groundwater for use in the restoration of a nearby wetlands area. Argonne National Laboratory has assisted the CCC/USDA by providing technical oversight for the aquifer restoration effort and facilities during this review period. This document presents overviews of the aquifer restoration facilities (Section 2) and system operations (Section 3), then describes groundwater production results (Section 4), groundwater treatment results (Section 5), and associated groundwater monitoring, system modifications, and costs during the review period (Section 6). Section 7 summarizes the present year of operation. Performance prior to December 1, 2009, has been reviewed previously (Argonne 2005, 2006, 2008, 2009a, 2010).

LaFreniere, L. M. (Environmental Science Division)

2011-03-11T23:59:59.000Z

45

Summary of operations and performance of the Utica aquifer and North Lake Basin wetlands restoration project in December 2008-November 2009.  

SciTech Connect (OSTI)

This document summarizes the performance of the groundwater restoration systems installed by the Commodity Credit Corporation of the U.S. Department of Agriculture (CCC/USDA) at the former CCC/USDA grain storage facility in Utica, Nebraska, during the fifth year of system operation, from December 1, 2008, until November 30, 2009. Performance in earlier years was reported previously (Argonne 2005, 2006, 2008, 2009a). In the project at Utica, the CCC/USDA is cooperating with multiple state and federal agencies to remove carbon tetrachloride contamination from a shallow aquifer underlying the town and to provide supplemental treated groundwater for use in the restoration of a nearby wetlands area. Argonne National Laboratory has assisted the CCC/USDA by providing technical oversight for the aquifer restoration effort and facilities during this review period. This document presents overviews of the aquifer restoration facilities (Section 2) and system operations (Section 3), then describes groundwater production results (Section 4), groundwater treatment results (Section 5), and associated groundwater monitoring, system modifications, and costs during the review period (Section 6). Section 7 summarizes the present year of operation.

LaFreniere, L. M.; Environmental Science Division

2010-05-25T23:59:59.000Z

46

The Economic Impact of the Natural Gas Industry and the Marcellus Shale Development in West Virginia in 2009  

E-Print Network [OSTI]

The Economic Impact of the Natural Gas Industry and the Marcellus Shale Development in West for this research was provided by the West Virginia Oil and Natural Gas Association (WVONGA). The opinions herein Natural gas is a colorless, odorless, and tasteless fuel that is used by households, manufacturers

Mohaghegh, Shahab

47

Evaluation of Devonian-shale potential in Ohio  

SciTech Connect (OSTI)

The purpose of this report is to inform interested oil and gas operators about EGSP results as they pertain to the Devonian gas shales of the Appalachian basin in eastern Ohio. Geologic data and interpretations are summarized, and areas where the accumulation of gas may be large enough to justify commercial production are outlined. Because the data presented in this report are generalized and not suitable for evaluation of specific sites for exploration, the reader should consult the various reports cited for more detail and discussion of the data, concepts, and interpretations presented. A complete list of EGSP sponsored work pertinent to the Devonian shales in Ohio is contained as an appendix to this report. Radioactive shale zones are also mapped.

Not Available

1981-01-01T23:59:59.000Z

48

Characterization of an Eastern Kentucky Devonian Shales well using a naturally fractured, layered reservoir description  

E-Print Network [OSTI]

of gas in place. ' Although production from the Devonian Shales began as early as 1821, only an estimated 2. 5 Tscf of gas had been produced through 1980, z with estimates of remaining recoverable gas ranging from 27 Tscf using a current technology... scenario, to 42 Tscf by applying advanced technology. ' Current production frotn the Devonian Shales of the Appalachian Basin is estimated at 0. 2 Tscf per year. ' The Devonian S hales is actively being developed in large portions of Pennsylvania, West...

Jochen, John Edward

1993-01-01T23:59:59.000Z

49

Reservoir Characterization and Enhanced Oil Recovery Potential in Middle Devonian Dundee Limestone Reservoirs, Michigan Basin, USA.  

E-Print Network [OSTI]

?? Middle Devonian Rogers City and subjacent Dundee Limestone formations have combined oil production in excess of 375 MMBO. In general, hydrocarbon production occurs in (more)

Abduslam, Abrahim

2012-01-01T23:59:59.000Z

50

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

SciTech Connect (OSTI)

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.

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

2010-01-01T23:59:59.000Z

51

Reactive gases evolved during pyrolysis of Devonian oil shale  

SciTech Connect (OSTI)

Computer modeling of oil shale pyrolysis is an important part of the Lawrence Livermore National Laboratory (LLNL) Oil Shale Program. Models containing detailed chemistry have been derived from an investigation of Colorado oil shale. We are currently attempting to use models to treat more completely reactions of nitrogen and sulfur compounds in the retort to better understand emissions. Batch retorting work on Devonian oil shale is proving particularly useful for this study of nitrogen/sulfur chemistry. Improved analytical methods have been developed to quantitatively determine reactive volatiles at the parts-per-million level. For example, the triple quadrupole mass spectrometer (TQMS) is used in the chemical ionization (CI) mode to provide real-time analytical data on ammonia evolution as the shale is pyrolyzed. A heated transfer line and inlet ensure rapid and complete introduction of ammonia to the instrument by preventing water condensation. Ammonia and water release data suitable for calculating kinetic parameters have been obtained from a New Albany Shale sample. An MS/MS technique with the TQMS in the electron ionization (EI) mode allows hydrogen sulfide, carbonyl sulfide, and certain trace organic sulfur compounds to be monitored during oil shale pyrolysis. Sensitivity and selectivity for these compounds have been increased by applying artificial intelligence techniques to tuning of the spectrometer. Gas evolution profiles (100 to 900/sup 0/C) are reported for hydrogen sulfide, water, ammonia, and trace sulfur species formed during pyrolysis of Devonian oil shale. Implications for retorting chemistry are discussed. 18 refs., 11 figs., 3 tabs.

Coburn, T.T.; Crawford, R.W.; Gregg, H.R.; Oh, M.S.

1986-11-01T23:59:59.000Z

52

Preliminary effects of Marcellus shale drilling on Louisiana waterthrush in West Virginia  

SciTech Connect (OSTI)

Preliminary effects of Marcellus shale drilling on Louisiana Waterthrush in West Virginia Page 1 of 1 Doug Becker and James Sheehan, WV Cooperative Fish and Wildlife Research Unit, West Virginia Univ., Morgantown, WV 26506, USA; Petra Bohall Wood, U.S. Geological Survey, WV Cooperative Fish and Wildlife Research Unit, West Virginia Univ., Morgantown, WV 26506, USA; Harry Edenborn, National Energy Technology Laboratory, U.S. Department of Energy, Pittsburgh, PA 15236, USA. Spurred by technological advances and high energy prices, extraction of natural gas from Marcellus shale is increasing in the Appalachian Region. Because little is known about effects on wildlife populations, we studied immediate impacts of oil and gas CO&G) extraction on demographics and relative abundance of Louisiana Waterthrush'CLOWA), a riparian obligate species, to establish a baseline for potential future changes. Annually in 2008-2010, we conducted point counts, monitored Mayfield nesting success, spotted-mapped territories, and measured habitat quality using the EPA Rapid Bioassessment protocol for high gradient streams and a LOWA Habitat Suitability Index CHSI) on a 4,100 ha study area in northern West Virginia. On 11 streams, the stream length affected by O&G activities was 0-58%. Relative abundance, territory denSity, and nest success varied annually but were not significantly different across years. Success did not differ between impacted and unimpacted nests, but territory density had minimal correlation with percent of stream impacted by O&G activities. Impacted nests had lower HSI values in 2010 and lower EPA indices in 2009. High site fidelity could mask the immediate impacts of habitat disturbance from drilling as we measured return rates of 57%. All returning individuals were on the same stream they were banded and 88% were within 250 m of their territory from the previous year. We also observed a spatial shift in LOWA territories, perhaps in response to drilling activities. Preliminary results identified few differences at low habitat disturbance levels but highlight the need for continued monitoring with increasing disturbance. file:

Becker, D.; Sheehan, J.; Wood, P.B.; Edenborn, H.M.

2011-01-01T23:59:59.000Z

53

Depositional Model of the Marcellus Shale in West Virginia Based on Facies Analysis  

SciTech Connect (OSTI)

A lithologic analysis of well exposed Marcellus outcrops has identified six different facies in West Virginia and neighboring states: (1) light gray calcareous shale, (2) fossiliferous limestone, (3) black calcareous shale, (4) black noncalcareous shale, (5) dark gray noncalcareous shale, and (6) K-bentonite. Close interbedding of these rock types attests to a complex, ever-changing environment on the eastern foreland ramp of the Appalachian Basin. The environmental setting was clearly not a deep trough, permanently anoxic, salinity stratified, sediment starved, and populated exclusively by phytoplanktonthe traditional depositional model. To the contrary, our sedimentary data suggest a rather shallow water depth, intermittent anoxia, normal-marine salinity, a fluctuating input of siliciclastic mud, and faunal communities of low and moderate diversity. Interbedding of the shale and limestone lithofacies as well as the vertical stacking of facies associations is explained most simply by fluctuations in water depth coupled with fluctuations in sediment supply. The sea floor was, at times, immediately below wave base (Facies 1 and 2), around the depth of the thermocline (Facies 2 and 3), or below the thermocline (Facies 4 and 5), relative sea level changing through two sequences of lowstand, transgression, and highstand. Simultaneously the supply of siliciclastic mud was greater at times of lowstand (increased erosion) and highstand (prograding shoreline), and the supply smaller during transgression (sediment stored in distant coastal plain).

Bruner, Kathy

2011-11-14T23:59:59.000Z

54

Evaluation of massive hydraulic fracturing experiments in the Devonian Shales in Lincoln County, West Virginia  

E-Print Network [OSTI]

EVALUATION OF MASSIVE HYDRAULIC FRACTURING EXPERIMENTS IN THE DEVONIAN SHALES IN LINCOLN COUNTY, WEST VIRGINIA A Thesis by KAREN ELAINE HOLGATE Submitted to the Graduate College of Texas ALM University in partial fulfillment... of the requirements for the degree of MASTER OF SCIENCE May 1987 Major Subject: Petroleum Engineering EVALUATION OF MASSIVE HYDRAULIC FRACTURING EXPERIMENTS IN THE DEVONIAN SHALES IN LINCOLN COUNTY, WEST VIRGINIA A Thesis by KAREN ELAINE HDLGATE Approved...

Holgate, Karen Elaine

1987-01-01T23:59:59.000Z

55

Effects of stimulation/completion practices on Eastern Devonian Shale well productivity  

E-Print Network [OSTI]

in the Devonian shale, ' then the degree of fracture density and fracture preferential direction caused by these stresses should dictate the choice of stimulation method. Young states that fracture orientation will be dictated by the in-situ stress field...EFFECTS OF STIMULATION/COMPLETION PRACTICES ON EASTERN DEVONIAN SHALE WELL PRODUCTIVITY A Thesis by TIMOTHY RAY NEARING Submitted to the Office of Graduate Studies Texas A&M University in partial fulfillment of the requirements for the degree...

Nearing, Timothy Ray

1988-01-01T23:59:59.000Z

56

Shale Webinar Series to Start September 13th The Penn State Marcellus Education Team will be offering a new monthly Shale webinar series beginning  

E-Print Network [OSTI]

Shale Webinar Series to Start September 13th The Penn State Marcellus Education Team will be offering a new monthly Shale webinar series beginning Thursday, September 13th from 1:00 to 2:00 PM. Tom the series with an overview of trends and updates on shale development. Tom will provide an analysis of shale

57

Bitumen accumulation in Grosmont platform complex, Upper Devonian, Alberta, Canada  

SciTech Connect (OSTI)

The Upper Devonian Grosmont Formation, a broad carbonate platform complex in Alberta, Canada, contains an estimated 300 billion bbl of bitumen. It has been suggested that these vast reserves are related to Lower Cretaceous Athabasca oil sands. Detailed gas chromatographic-mass spectrometric studies of a wide range of biologic marker compounds confirm this suggestion. The Grosmont Formation contains bitumen of similar maturity and source to the Athabasca deposit, but it has been subjected to a greater degree of biodegradation and water washing, possibly as a result of its reservoir rock characteristics. The difference in the degree of biodegradation is manifested by the absence of bicyclic terpanes and by the reduced concentrations of the C/sub 30/ and the 22R epimers of the extended hopanes in the Grosmont bitumen. Also, the greater degree of water washing of the Grosmont bitumen is inferred from the observed distribution of the bicyclic, tricyclic, and tetracyclic terpenoid sulfides, which shows a characteristic loss of the lower molecular weight members in the carbonate bitumen. The correlation established here between the two deposits suggests that if the precursor oil has indeed undergone long-distance migration, the Paleozoic carbonates could have acted as a path for migration. Finally, the observed distribution of steranes in the Grosmont bitumen corresponds to the suggestion that the Mannville Group shales were not the major source rocks of the oil-sand and carbonate bitumen accumulations of northern Alberta. 11 figures, 6 tables.

Hoffmann, C.F.; Strausz, O.P.

1986-09-01T23:59:59.000Z

58

Evolution of porosity and geochemistry in Marcellus Formation black shale during weathering  

SciTech Connect (OSTI)

Soils developed on the Oatka Creek member of the Marcellus Formation in Huntingdon, Pennsylvania were analyzed to understand the evolution of black shale matrix porosity and the associated changes in elemental and mineralogical composition during infiltration of water into organic-rich shale. Making the reasonable assumption that soil erosion rates are the same as those measured in a nearby location on a less organic-rich shale, we suggest that soil production rates have on average been faster for this black shale compared to the gray shale in similar climate settings. This difference is attributed to differences in composition: both shales are dominantly quartz, illite, and chlorite, but the Oatka Creek member at this location has more organic matter (1.25 wt.% organic carbon in rock fragments recovered from the bottom of the auger cores and nearby outcrops) and accessory pyrite. During weathering, the extremely low-porosity bedrock slowly disaggregates into shale chips with intergranular pores and fractures. Some of these pores are eitherfilled with organic matter or air-filled but remain unconnected, and thus inaccessible to water. Based on weathering bedrock/soil profiles, disintegration is initiated with oxidation of pyrite and organic matter, which increases the overall porosity and most importantly allows water penetration. Water infiltration exposes fresh surface area and thus promotes dissolution of plagioclase and clays. As these dissolution reactions proceed, the porosity in the deepest shale chips recovered from the soil decrease from 9 to 7% while kaolinite and Fe oxyhydroxides precipitate. Eventually, near the land surface, mineral precipitation is outcompeted by dissolution or particle loss of illite and chlorite and porosity in shale chips increases to 20%. As imaged by computed tomographic analysis, weathering causes i) greater porosity, ii) greater average length of connected pores, and iii) a more branched pore network compared to the unweathered sample. This work highlights the impact of shale water O2interactions in near-surface environments: (1) black shale weathering is important for global carbon cycles as previously buried organic matter is quickly oxidized; and (2) black shales weather more quickly than less organic- and sulfide-rich shales, leading to high porosity and mineral surface areas exposed for clay weathering. The fast rates of shale gas exploitation that are ongoing in Pennsylvania, Texas and other regions in the United States may furthermore lead to release of metals to the environment if reactions between water and black shale are accelerated by gas development activities in the subsurface just as they are by low-temperature processes in ourfield study.

Jin, Lixin [University of Texas at El Paso] [University of Texas at El Paso; Ryan, Mathur [Juniata College, Huntingdon] [Juniata College, Huntingdon; Rother, Gernot [ORNL] [ORNL; Cole, David [Ohio State University] [Ohio State University; Bazilevskaya, Ekaterina [Pennsylvania State University, University Park, PA] [Pennsylvania State University, University Park, PA; Williams, Jennifer [Pennsylvania State University] [Pennsylvania State University; Alex, Carone [Pennsylvania State University] [Pennsylvania State University; Brantley, S. L. [Pennsylvania State University, University Park, PA] [Pennsylvania State University, University Park, PA

2013-01-01T23:59:59.000Z

59

Evolution of porosity and geochemistry in Marcellus Formation black shale during weathering  

SciTech Connect (OSTI)

Soils developed on the Oatka Creek member of the Marcellus Formation in Huntingdon, Pennsylvania were analyzed to understand the evolution of black shale matrix porosity and the associated changes in elemental and mineralogical composition during infiltration of water into organic-rich shale. Making the reasonable assumption that soil erosion rates are the same as those measured in a nearby location on a less organic-rich shale, we suggest that soil production rates have on average been faster for this black shale compared to the gray shale in similar climate settings. This difference is attributed to differences in composition: both shales are dominantly quartz, illite, and chlorite, but the Oatka Creek member at this location has more organic matter (1.25 wt% organic carbon in rock fragments recovered from the bottom of the auger cores and nearby outcrops) and accessory pyrite. During weathering, the extremely low-porosity bedrock slowly disaggregates into shale chips with intergranular pores and fractures. Some of these pores are either filled with organic matter or air-filled but remain unconnected, and thus inaccessible to water. Based on weathering bedrock/soil profiles, disintegration is initiated with oxidation of pyrite and organic matter, which increases the overall porosity and most importantly allows water penetration. Water infiltration exposes fresh surface area and thus promotes dissolution of plagioclase and clays. As these dissolution reactions proceed, the porosity in the deepest shale chips recovered from the soil decrease from 9 to 7 % while kaolinite and Fe oxyhydroxides precipitate. Eventually, near the land surface, mineral precipitation is outcompeted by dissolution or particle loss of illite and chlorite and porosity in shale chips increases to 20%. As imaged by computed tomographic analysis, weathering causes i) greater porosity, ii) greater average length of connected pores, and iii) a more branched pore network compared to the unweathered sample. This work highlights the impact of shale-water-O2 interactions in near-surface environments: (1) black shale weathering is important for global carbon cycles as previously buried organic matter is quickly oxidized; and (2) black shales weather more quickly than less organic- and sulfide-rich shales, leading to high porosity and mineral surface areas exposed for clay weathering. The fast rates of shale gas exploitation that are ongoing in Pennsylvania, Texas and other regions in the United States may furthermore lead to release of metals to the environment if reactions between water and black shale are accelerated by gas development activities in the subsurface just as they are by low-temperature processes in our field study.

Jin, Lixin [ORNL; Mathur, Ryan [Juniata College, Huntingdon; Rother, Gernot [ORNL; Cole, David [Ohio State University; Bazilevskaya, Ekaterina [Pennsylvania State University, University Park, PA; Williams, Jennifer [Pennsylvania State University; Carone, Alex [Pennsylvania State University, University Park, PA; Brantley, Susan L [ORNL

2013-01-01T23:59:59.000Z

60

Architecture of the Middle Devonian Kvamshesten Group, western Norway: sedimentary response to deformation above a ramp-flat  

E-Print Network [OSTI]

Architecture of the Middle Devonian Kvamshesten Group, western Norway: sedimentary response. ANDERSEN 1 1Department of Geology, University of Oslo, Pb 1047 Blindern, 0316 Oslo, Norway 2present address." Geological Survey of Norway, 7491 Trondheim, Norway Abstract: The Mid-Devonian Kvamshesten basin in western

Andersen, Torgeir Bjørge

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


61

Plants of Devonian-Mississippian black shales, eastern interior, USA  

SciTech Connect (OSTI)

Macrofossils of the New Albany shale and equivalents of Late Devonian of Early Mississippian age in the east-central United States are known from three main floras or assemblages. One flora is almost entirely composed of Callixylon logs, slabs, and slivers, presumed to be driftwood permineralized after burial. Callixylon fossils are most abundant in the upper part of the Clegg Creek Member of the New Albany shale (Famennian) and equivalent strata in western New York, Ohio, and contiguous areas, perhaps because these Propymnosperms reached the zenith of their development at that time. A second, and later, flora consists principally of permineralized wood pieces (phosphatized free-wood or concretions) of stems, rachises, petioles, and possibly even mid-veins of pinnules of diverse members of the Lycopsida, Sphenopsida, Cladoxylales, Coenopteridales, Progymnospermae, and Pteridospermae. The principal concentration of these stem and petiolar segments is in the Falling Run Member of Sanderson Formation of the New Albany shale on the west side of the Cincinnati arch in southern Indiana and Kentucky, and in central Kentucky in the low saddle between the Cincinnati arch proper and its southward extension as the Nashville dome. The third type of macrofossil plant assemblage is consituted of Foerstia. These plants are considered to be algal in origin and indicate no clear relationship either to distance from shore or depth of water. The main concentration is in middle and lower New Albany shale and equivalents. It is also found sparingly in West Virginia and Michigan and much farther west (one specimen from the Exshaw shale of Montana).

Cross, A.T.

1983-03-01T23:59:59.000Z

62

MID-LATE DEVONIAN CALCIFIED MARINE ALGAE AND CYANOBACTERIA, SOUTH CHINA  

E-Print Network [OSTI]

MID-LATE DEVONIAN CALCIFIED MARINE ALGAE AND CYANOBACTERIA, SOUTH CHINA QI FENG,1 YI-MING GONG,1 contain microfossils generally regarded as calcified algae and cyanobacteria. These are present in 61 out with differing degrees of confidence, and placed in algae, cyanobacteria or microproblematica. Algae: Halysis

Riding, Robert

63

2006 Nature Publishing Group A Devonian tetrapod-like fish and the  

E-Print Network [OSTI]

© 2006 Nature Publishing Group A Devonian tetrapod-like fish and the evolution of the tetrapod body vertebrates (tetrapods) to lobe-finned fish (sarcopterygians) is well established, but the origin of major changes. Here we report the discovery of a well-preserved species of fossil sarcopterygian fish from

Bechtold, Jill

64

Sedimentology of gas-bearing Devonian shales of the Appalachian Basin  

SciTech Connect (OSTI)

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.

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

1981-01-01T23:59:59.000Z

65

Natural gas potential of the New Albany shale group (Devonian-Mississippian) in southeastern Illinois  

SciTech Connect (OSTI)

Data from geologic and geochemical studies of the New Albany shale group indicate that a 19-country area of southeastern Illinois is a favorable area to explore for gas in Devonian shale. Although gas shows in the shales have been encountered in several wells drilled in this area, no attempts were made to complete or evaluate a shale gas well until 1979. It is found that conventional rotary drilling with mud base drilling fluids likely causes extensive formation damage and may account for the paucity of gas shows and completion attempts in the Devonian shales; therefore, commercial production of shale gas in Illinois probably will require novel drilling completion techniques not commonly used by local operators. 16 refs.

Cluff, R.M.; Dickerson, D.R.

1982-04-01T23:59:59.000Z

66

Installation of a Devonian Shale Reservoir Testing Facility and acquisition of reservoir property measurements  

SciTech Connect (OSTI)

In October, a contract was awarded for the Installation of a Devonian Shale Reservoir Testing Facility and Acquisition of Reservoir Property measurements from wells in the Michigan, Illinois, and Appalachian Basins. Geologic and engineering data collected through this project will provide a better understanding of the mechanisms and conditions controlling shale gas production. This report summarizes the results obtained from the various testing procedures used at each wellsite and the activities conducted at the Reservoir Testing Facility.

Locke, C.D.; Salamy, S.P.

1991-09-01T23:59:59.000Z

67

Upper Devonian and Lower Mississippian conodont zones in Montana, Wyoming, and South Dakota  

E-Print Network [OSTI]

shale of the Sappington Member of the Three Forks Formation at another locality in the Bridger Range. The taxonomic section includes a discussion of 34 species, which are referred to 11 genera. Two new species of Dinodus and Siphonodella are described. 2...," Hannibal, and Chouteau Formations). Related to the problem of the Kinderhookian is that of the Chattanooga Shale of Tennessee and adjacent states. HASS (51, 52) by comparison with the New York Upper Devonian conodont se- quence, firmly dated the Chattanooga...

Klapper, G.

1966-05-23T23:59:59.000Z

68

Installation of a Devonian Shale Reservoir Testing Facility and acquisition of reservoir property measurements. Final report  

SciTech Connect (OSTI)

In October, a contract was awarded for the Installation of a Devonian Shale Reservoir Testing Facility and Acquisition of Reservoir Property measurements from wells in the Michigan, Illinois, and Appalachian Basins. Geologic and engineering data collected through this project will provide a better understanding of the mechanisms and conditions controlling shale gas production. This report summarizes the results obtained from the various testing procedures used at each wellsite and the activities conducted at the Reservoir Testing Facility.

Locke, C.D.; Salamy, S.P.

1991-09-01T23:59:59.000Z

69

Source contributions to Devonian granite magmatism near the Laurentian border, New Hampshire and Western Maine, USA  

E-Print Network [OSTI]

Source contributions to Devonian granite magmatism near the Laurentian border, New Hampshire complex, a suite of mainly granitic intrusions in New Hampshire and western Maine, are used to evaluate.56­15.58] and an areally dominant granite [370F2 Ma; eNd (at 370 Ma)=?7.0 to ?0.6; initial 207 Pb/204 Pb=15

Solar, Gary S.

70

The use of Devonian oil shales in the production of portland cement  

SciTech Connect (OSTI)

The Lafarge Corporation operates a cement plant at Alpena, Michigan in which Antrim shale, a Devonian oil shale, is used as part of the raw material mix. Using this precedent the authors examine the conditions and extent to which spent shale might be utilized in cement production. They conclude that the potential is limited in size and location but could provide substantial benefit to an oil shale operation meeting these criteria.

Schultz, C.W.; Lamont, W.E. [Alabama Univ., University, AL (United States); Daniel, J. [Lafarge Corp., Alpena, MI (United States)

1991-12-31T23:59:59.000Z

71

A study of the effects of stimulation on Devonian Shale gas well performance  

E-Print Network [OSTI]

of actual production data from producing Devonian Shale gas wells throughout the Appalachian Basin. These comparisons are of limited use, however, because they fail to take into account recently developed stimulation technologies and because compari... by analysis of these data. Unfortunately, too little data are available for wells stimulated using current technologies. This study included no production data from wells stimulated by radial (tailored-pulse) fracturing methods. These data are vital...

Zuber, Michael Dean

1985-01-01T23:59:59.000Z

72

Copyright 2013 by The American Association of Petroleum Geologists. DOI: 10.1306/13391711M1023589  

E-Print Network [OSTI]

Middle Devonian Marcellus Shale and late Devonian New Albany Shale samples were argon- ion milled be a significant contributor to the overall porosity of shale intervals. METHODS Samples of the Devonian New Albany1023589 13 SEM Observations on Ion-milled Samples of Devonian Black Shales from Indiana and New York

Polly, David

73

Northeastern Geology & Environmental Sciences, v. 30, no. 4, 2008, p. 330-343. STABLE ISOTOPE SIGNATURE OF MIDDLE DEVONIAN SEAWATER FROM HAMILTON  

E-Print Network [OSTI]

SIGNATURE OF MIDDLE DEVONIAN SEAWATER FROM HAMILTON GROUP BRACHIOPODS, CENTRAL NEW YORK STATE Bruce Selleck and Drew Koff Department of Geology, 13 Oak Drive, Colgate University, Hamilton, NY 13346; bselleck the Middle Devonian Hamilton Group of Central New York State. The sample set includes multiple specimens

Soja, Constance M.

74

Studies of the New Albany Shale (Devonian and Mississippian) and equivalent strata in Indiana  

SciTech Connect (OSTI)

A formation of black carbonaceous shale, later named the New Albany Shale, was first recognized in 1837 and reported in 1839 by David D. Owen. Since then, the New Albany has been the subject of numerous investigations by individuals affiliated with the Indiana Geological Survey and others. The present comprehensive investigation, involves petrology, mineralogy, stratigraphy, geomorphology, organic and inorganic geochemistry, and physical properties. The lower part of the New Albany Shale is late Middle Devonian in age, and the upper part is Early Mississippian in age.

Hasenmueller, N.R.; Woodard, G.S. (eds.)

1981-09-01T23:59:59.000Z

75

The Late Devonian mass extinction was unusually protracted and ecologically selective, with preferential diversity losses among reef-  

E-Print Network [OSTI]

of the Phanerozoic (Sepkoski, 1986), with species- level extinction in the marine biosphere estimated to have beenABSTRACT The Late Devonian mass extinction was unusually protracted and ecologically selective have investigated the link between the extinction's unique character- istics and changes

Sageman, Brad

76

Demonstration projects for coalbed methane and Devonian shale gas: Final report. [None  

SciTech Connect (OSTI)

In 1979, the US Department of Energy provided the American Public Gas Association (APGA) with a grant to demonstrate the feasibility of bringing unconventional gas such as methane produced from coalbeds or Devonian Shale directly into publicly owned utility system distribution lines. In conjunction with this grant, a seven-year program was initiated where a total of sixteen wells were drilled for the purpose of providing this untapped resource to communities who distribute natural gas. While coalbed degasification ahead of coal mining was already a reality in several parts of the country, the APGA demonstration program was aimed at actual consumer use of the gas. Emphasis was therefore placed on degasification of coals with high methane gas content and on utilization of conventional oil field techniques. 13 figs.

Verrips, A.M.; Gustavson, J.B.

1987-04-01T23:59:59.000Z

77

Relationship between bitumen maturity and organic facies in Devonian shales from the Appalachian basin  

SciTech Connect (OSTI)

Variation in several bitumen maturity parameters was studied in a core of Devonian shale from the central Appalachian basin. Kerogens in the shales are at maturity levels equivalent to the early stages of oil generation and range in composition from Type III-IV to Type II-III. Maturity parameters based on steranes, terpanes, and n-alkanes exhibit fluctuations that are unrelated to thermal maturity changes in the core. The parameters correlate with one another to a high degree and appear to be directly or indirectly related to the organic facies of the shales. The maturity level indicated by each parameter increases with total organic carbon (TOC) content and hydrogen index value. The greatest variation occurs in rocks with TOC values below 2% and hydrogen index values below 250. The data provide a good opportunity to examine the dependency of bitumen maturity on organic facies, and they highlight a caveat to be considered during interpretation.

Daly, A.R.

1988-01-01T23:59:59.000Z

78

Devonian oil shale of the eastern United States: a major American energy resource  

SciTech Connect (OSTI)

The eastern Devonian oil shale resource can yield 400 billion (400 X 10/sup 9/) bbl of synthetic oil, if all surface and near-surface shales were strip or deep mined for above-ground hydroretorting. Experimental work, in equipment capable of processing up to 1 ton/h of shale, has confirmed the technical and economic feasibility of aboveground hydroretorting of oil shales. Work done to date on nearly 500 samples from 12 states indicates that the HYTORT Process can give organic carbon recoveries from 2 to 2.5 times those of conventional retorting of the Devonian shales, so that the HYTORT Process yields 25 to 30 gallons per ton on syncrude at many localities, compared with 10 to 15 gallons per ton using Fischer Assay retort methods. Criteria for inclusion of shale in estimates of recoverable resources for the HYTORT Process are: (1) organic carbon of at least 10% by weight; (2) overburden of less than 200 feet (59 meters); (3) volumetric stripping ratios of less than 2.5 to 1; and (4) stratigraphic thickness of 10 feet (3 meters) or more. Resource estimates include: Kentucky (Ohio, New Albany, and Sunbury shales), 190 billion (190 X 10/sup 9/) barrels (bbl); Ohio (Ohio and Sunbury shales), 140 billion bbl; Tennessee (Chattanooga shale), 44 billion bbl; Indiana (New Albany shale), 40 billion bbl; Michigan (Antrim shale), 5 billion bbl; and Alabama (Chattanooga shale), 4 billion bbl. Recoverable resources have not been identified in West Virginia, Georgia, Oklahoma, Illinois, Arkansas, or Missouri outcrops. Co-production of uranium and metals is a possibility in the areas favorable for syncrude production.

Matthews, R.D.; Janka, J.C.; Dennison, J.M.

1980-01-01T23:59:59.000Z

79

Secondary recovery from a stromatoporoid buildup: Devonian Duperow Formation, Ridgelawn field, Montana  

SciTech Connect (OSTI)

Ridgelawn field is located in Richland County, Montana, in the western part of the Williston basin. It is a multiple-pay field, with production from ordovician, Devonian, and Mississippian carbonates. Discovered in 1980, the field was recently unitized in the Devonian Duperow Formation for purposes of secondary recovery by waterflood. In this part of the Williston, the Duperow consists of a repetitive succession of shoaling-upward carbonate cycles, each deposited under increasingly restricted conditions on a shallow marine shelf. Production at Ridgelaw occurs from dolomites within one of these cycles, cycle IIIa. Three separate, laterally continuous porosity zones (here termed a, b, and c, from lowest to highest) are recognized and mapped individually in the field. The reservoir has a lensoidal geometry; porous dolomite thins and grades laterally into tight carbonate. The Duperow pool at Ridgelawn is a solution gas drive reservoir. Computer log analysis of the Duperow pay interval indicates an average true porosity of 11.8% and an average initial water saturation of 17.7%. Net pay, defined as greater than 5% crossplot porosity, averages 16.6 ft across the field. Petrographic analysis and log calibration suggests that different facies in each of the three porosity zones were preferentially dolomitized to create reservoir-quality rock; each is now a sucrosic dolomite with intercrystalline porosity. Porosity can be occluded (most often in the upper two zones b and c) by both calcite and anhydrite cements. The lowermost zone, a, is related to a stromatoporoid/coralline bank, and has excellent but highly variable porosity and permeability. The two upper zones, b and c, are more finely crystalline dolomite and represent shallower water depositional facies. Maps for each zone, including porosity, porosity-feet, net pay, and water saturation were constructed and used for equity determination in the unit.

Little, L.D. (Conoco Inc., Casper, WY (USA))

1990-05-01T23:59:59.000Z

80

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

Proposed carbon management technologies include geologic sequestration of CO{sub 2}. A possible, but untested, strategy is to inject CO{sub 2} into organic-rich shales of Devonian age. Devonian black shales underlie approximately two-thirds of Kentucky and are generally thicker and deeper in the Illinois and Appalachian Basin portions of Kentucky. The Devonian black shales serve as both the source and trap for large quantities of natural gas; total gas in place for the shales in Kentucky is estimated to be between 63 and 112 trillion cubic feet. Most of this natural gas is adsorbed on clay and kerogen surfaces, analogous to the way methane is stored in coal beds. In coals, it has been demonstrated that CO{sub 2} is preferentially adsorbed, displacing methane at a ratio of two to one. Black shales may similarly desorb methane in the presence of CO{sub 2}. If black shales similarly desorb methane in the presence of CO{sub 2}, the shales may be an excellent sink for CO{sub 2} with the added benefit of serving to enhance natural gas production. The concept that black, organic-rich Devonian shales could serve as a significant geologic sink for CO{sub 2} is the subject this research. To accomplish this investigation, drill cuttings and cores will be selected from the Kentucky Geological Survey Well Sample and Core Library. CO{sub 2} adsorption analyses will be performed in order to determine the gas-storage potential of the shale and to identify shale facies with the most sequestration potential. In addition, new drill cuttings and sidewall core samples will be acquired to investigate specific black-shale facies, their uptake of CO{sub 2}, and the resultant displacement of methane. Advanced logging techniques (elemental capture spectroscopy) will be used to investigate possible correlations between adsorption capacity and geophysical log measurements.

Brandon C. Nuttall

2003-02-10T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


81

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

Proposed carbon management technologies include geologic sequestration of CO{sub 2}. A possible, but untested, strategy is to inject CO{sub 2} into organic-rich shales of Devonian age. Devonian black shales underlie approximately two-thirds of Kentucky and are generally thicker and deeper in the Illinois and Appalachian Basin portions of Kentucky. The Devonian black shales serve as both the source and trap for large quantities of natural gas; total gas in place for the shales in Kentucky is estimated to be between 63 and 112 trillion cubic feet. Most of this natural gas is adsorbed on clay and kerogen surfaces, analogous to the way methane is stored in coal beds. In coals, it has been demonstrated that CO{sub 2} is preferentially adsorbed, displacing methane at a ratio of two to one. Black shales may similarly desorb methane in the presence of CO{sub 2}. If black shales similarly desorb methane in the presence of CO{sub 2}, the shales may be an excellent sink for CO{sub 2} with the added benefit of serving to enhance natural gas production. The concept that black, organic-rich Devonian shales could serve as a significant geologic sink for CO{sub 2} is the subject this research. To accomplish this investigation, drill cuttings and cores will be selected from the Kentucky Geological Survey Well Sample and Core Library. CO{sub 2} adsorption analyses will be performed in order to determine the gas-storage potential of the shale and to identify shale facies with the most sequestration potential. In addition, new drill cuttings and sidewall core samples will be acquired to investigate specific black-shale facies, their uptake of CO{sub 2}, and the resultant displacement of methane. Advanced logging techniques (elemental capture spectroscopy) will be used to investigate possible correlations between adsorption capacity and geophysical log measurements.

Brandon C. Nuttall

2003-04-28T23:59:59.000Z

82

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

Proposed carbon management technologies include geologic sequestration of CO{sub 2}. A possible, but untested, strategy is to inject CO{sub 2} into organic-rich shales of Devonian age. Devonian black shales underlie approximately two-thirds of Kentucky and are generally thicker and deeper in the Illinois and Appalachian Basin portions of Kentucky. The Devonian black shales serve as both the source and trap for large quantities of natural gas; total gas in place for the shales in Kentucky is estimated to be between 63 and 112 trillion cubic feet. Most of this natural gas is adsorbed on clay and kerogen surfaces, analogous to the way methane is stored in coal beds. In coals, it has been demonstrated that CO{sub 2} is preferentially adsorbed, displacing methane at a ratio of two to one. Black shales may similarly desorb methane in the presence of CO{sub 2}. If black shales similarly desorb methane in the presence of CO{sub 2}, the shales may be an excellent sink for CO{sub 2} with the added benefit of serving to enhance natural gas production. The concept that black, organic-rich Devonian shales could serve as a significant geologic sink for CO{sub 2} is the subject this research. To accomplish this investigation, drill cuttings and cores will be selected from the Kentucky Geological Survey Well Sample and Core Library. CO{sub 2} adsorption analyses will be performed in order to determine the gas-storage potential of the shale and to identify shale facies with the most sequestration potential. In addition, new drill cuttings and sidewall core samples will be acquired to investigate specific black-shale facies, their uptake of CO{sub 2}, and the resultant displacement of methane. Advanced logging techniques (elemental capture spectroscopy) will be used to investigate possible correlations between adsorption capacity and geophysical log measurements.

Brandon C. Nuttall

2003-02-11T23:59:59.000Z

83

Tectonic and flexural significance of Middle Devonian graben-fill sequence in new Albany shale, central Kentucky  

SciTech Connect (OSTI)

The third tectonic phase of the Acadian orogeny began in the late Middle Devonian, and the sedimentary record of that event is largely restricted to the deeper, more proximal portions of the Appalachian foreland and Illinois intercratonic basins. Much of the intervening area, on and near the Cincinnati arch, was uplifted and subjected to erosion by movement on the peripheral bulge accompanying the initiation of the third tectonic phase. However, bulge movement also reactivated basement fault systems in Kentucky and created a series of grabens that were filled with eroded sediments and debris flows from adjacent horsts. Although rarely preserved, a buried Devonian graben along Carpenter Fork in Boyle County, central Kentucky, reveals such a sequence. The graben is bounded by upthrown blocks of Middle Devonian Boyle Dolomite, which also floors the graben. Within the graben a black-shale unit, apparently absent elsewhere, conformably overlies the Boyle and grades upward into debris-flow deposits represented by the Duffin breccia facies of the New Albany Shale. The Duffin contains clasts of the shale, as well as of chert, silicified fossils, and fine to boulder-size dolostone clasts eroded from the Boyle high on the flanks of the graben. The underlying shale also exhibits evidence of penecontemporaneous soft-sediment deformation related to the debris-flow emplacement of Boyle residue in the graben and due to later loading by the Duffin.

Barnett, S.F.; Ettensohn, F.R.; Mellon, C. (Univ. of Kentucky, Lexington (USA))

1989-08-01T23:59:59.000Z

84

Sequence stratigraphy, depositional environments, and regional mapping of the late Devonian interval, upper Three Forks Formation, Sanish Member, and lower Bakken Shale, U.S. portion of the Williston Basin.  

E-Print Network [OSTI]

??Cores of the Late Devonian upper Three Forks, Sanish, and lower Bakken units from eight wells were examined and described at the North Dakota core (more)

Sesack, Steven A.

2011-01-01T23:59:59.000Z

85

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

CO{sub 2} emissions from the combustion of fossil fuels have been linked to global climate change. Proposed carbon management technologies include geologic sequestration of CO{sub 2}. A possible, but untested, sequestration strategy is to inject CO{sub 2} into organic-rich shales. Devonian black shales underlie approximately two-thirds of Kentucky and are thicker and deeper in the Illinois and Appalachian Basin portions of Kentucky than in central Kentucky. The Devonian black shales serve as both the source and trap for large quantities of natural gas; total gas in place for the shales in Kentucky is estimated to be between 63 and 112 trillion cubic feet. Most of this natural gas is adsorbed on clay and kerogen surfaces, analogous to methane storage in coal beds. In coals, it has been demonstrated that CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. The concept that black, organic-rich Devonian shales could serve as a significant geologic sink for CO{sub 2} is the subject of current research. To accomplish this investigation, drill cuttings and cores were selected from the Kentucky Geological Survey Well Sample and Core Library. Methane and carbon dioxide adsorption analyses are being performed to determine the gas-storage potential of the shale and to identify shale facies with the most sequestration potential. In addition, sidewall core samples are being acquired to investigate specific black-shale facies, their potential CO{sub 2} uptake, and the resulting displacement of methane. Advanced logging techniques (elemental capture spectroscopy) are being investigated for possible correlations between adsorption capacity and geophysical log measurements. For the Devonian shale, average total organic carbon is 3.71 (as received) and mean random vitrinite reflectance is 1.16. Measured adsorption isotherm data range from 37.5 to 2,077.6 standard cubic feet of CO{sub 2} per ton (scf/ton) of shale. At 500 psia, adsorption capacity of the Lower Huron Member of the shale is 72 scf/ton. Initial estimates indicate a sequestration capacity of 5.3 billion tons CO{sub 2} in the Lower Huron Member of the Ohio shale in parts of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker portions of the Devonian shales in Kentucky. The black shales of Kentucky could be a viable geologic sink for CO{sub 2}, and their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2004-01-01T23:59:59.000Z

86

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

CO{sub 2} emissions from the combustion of fossil fuels have been linked to global climate change. Proposed carbon management technologies include geologic sequestration of CO{sub 2}. A possible, but untested, sequestration strategy is to inject CO{sub 2} into organic-rich shales. Devonian black shales underlie approximately two-thirds of Kentucky and are thicker and deeper in the Illinois and Appalachian Basin portions of Kentucky than in central Kentucky. The Devonian black shales serve as both the source and trap for large quantities of natural gas; total gas in place for the shales in Kentucky is estimated to be between 63 and 112 trillion cubic feet. Most of this natural gas is adsorbed on clay and kerogen surfaces, analogous to methane storage in coal beds. In coals, it has been demonstrated that CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. The concept that black, organic-rich Devonian shales could serve as a significant geologic sink for CO{sub 2} is the subject of current research. To accomplish this investigation, drill cuttings and cores were selected from the Kentucky Geological Survey Well Sample and Core Library. Methane and carbon dioxide adsorption analyses are being performed to determine the gas-storage potential of the shale and to identify shale facies with the most sequestration potential. In addition, sidewall core samples are being acquired to investigate specific black-shale facies, their potential CO{sub 2} uptake, and the resulting displacement of methane. Advanced logging techniques (elemental capture spectroscopy) are being investigated for possible correlations between adsorption capacity and geophysical log measurements. For the Devonian shale, average total organic carbon is 3.71 percent (as received) and mean random vitrinite reflectance is 1.16. Measured adsorption isotherm data range from 37.5 to 2,077.6 standard cubic feet of CO{sub 2} per ton (scf/ton) of shale. At 500 psia, adsorption capacity of the Lower Huron Member of the shale is 72 scf/ton. Initial estimates indicate a sequestration capacity of 5.3 billion tons CO{sub 2} in the Lower Huron Member of the Ohio shale in parts of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker portions of the Devonian shales in Kentucky. The black shales of Kentucky could be a viable geologic sink for CO{sub 2}, and their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2004-04-01T23:59:59.000Z

87

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

CO{sub 2} emissions from the combustion of fossil fuels have been linked to global climate change. Proposed carbon management technologies include geologic sequestration of CO{sub 2}. A possible, but untested, sequestration strategy is to inject CO{sub 2} into organic-rich shales. Devonian black shales underlie approximately two-thirds of Kentucky and are thicker and deeper in the Illinois and Appalachian Basin portions of Kentucky than in central Kentucky. The Devonian black shales serve as both the source and trap for large quantities of natural gas; total gas in place for the shales in Kentucky is estimated to be between 63 and 112 trillion cubic feet. Most of this natural gas is adsorbed on clay and kerogen surfaces, analogous to methane storage in coal beds. In coals, it has been demonstrated that CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. The concept that black, organic-rich Devonian shales could serve as a significant geologic sink for CO{sub 2} is the subject of current research. To accomplish this investigation, drill cuttings and cores were selected from the Kentucky Geological Survey Well Sample and Core Library. Methane and carbon dioxide adsorption analyses are being performed to determine the gas-storage potential of the shale and to identify shale facies with the most sequestration potential. In addition, sidewall core samples are being acquired to investigate specific black-shale facies, their potential CO{sub 2} uptake, and the resulting displacement of methane. Advanced logging techniques (elemental capture spectroscopy) are being investigated for possible correlations between adsorption capacity and geophysical log measurements. For the Devonian shale, average total organic carbon is 3.71 (as received) and mean random vitrinite reflectance is 1.16. Measured adsorption isotherm data range from 37.5 to 2,077.6 standard cubic feet of CO{sub 2} per ton (scf/ton) of shale. At 500 psia, adsorption capacity of the Lower Huron Member of the shale is 72 scf/ton. Initial estimates indicate a sequestration capacity of 5.3 billion tons CO{sub 2} in the Lower Huron Member of the Ohio shale in parts of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker portions of the Devonian shales in Kentucky. The black shales of Kentucky could be a viable geologic sink for CO{sub 2}, and their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2003-10-29T23:59:59.000Z

88

Parameter sensitivity analysis of tailored-pulse loading stimulation of Devonian gas shale  

SciTech Connect (OSTI)

An evaluation of three tailored-pulse loading parameters has been undertaken to access their importance in gas well stimulation technology. This numerical evaluation was performed using STEALTH finite-difference codes and was intended to provide a measure of the effects of various tailored-pulse load configurations on fracture development in Devonian gas shale. The three parameters considered in the sensitivity analysis were: loading rate; decay rate; and sustained peak pressures. By varying these parameters in six computations and comparing the relative differences in fracture initiation and propagation the following conclusions were drawn: (1) Fracture initiation is directly related to the loading rate aplied to the wellbore wall. Loading rates of 10, 100 and 1000 GPa/sec were modeled. (2) If yielding of the rock can be prevented or minimized, by maintaining low peak pressures in the wellbore, increasing the pulse loading rate, to say 10,000 GPa/sec or more, should initiate additional multiple fractures. (3) Fracture initiation does not appear to be related to the tailored-pulse decay rate. Fracture extension may be influenced by the rate of decay. The slower the decay rate, the longer the crack extension. (4) Fracture initiation does not appear to be improved by a high pressure plateau in the tailored-pulse. Fracture propagation may be enhanced if the maintained wellbore pressure plateau is of sufficient magnitude to extent the range of the tangential tensile stresses to greater radial distances. 26 figures, 2 tables.

Barbour, T.G.; Mihalik, G.R.

1980-11-01T23:59:59.000Z

89

Inorganic geochemistry of Devonian shales in southern West Virginia: geographic and stratigraphic trends  

SciTech Connect (OSTI)

Samples of cuttings from twenty-one wells and a core from a single well in southern West Virginia were analyzed for major and minor elements: silicon, aluminum, iron, magnesium, calcium, sodium, titanium, phosphorus, manganese, sulfur, zinc, and strontium. Stratigraphic and geographic controls on elemental abundances were studied through canonical correlations, factor analyses, and trend surface analyses. The most abundant elements, silicon and aluminum, show gradual trends through the stratigraphic column of most wells, with silicon increasing and aluminum decreasing up-section. Other elements such as calcium, sulfur, and titanium change abruptly in abundance at certain stratigraphic boundaries. Important geographic trends run east-west: for instance, one can see an increase in sulfur and a decrease in titanium to the west; and a decrease in silicon from the east to the central part of the study area, then an increase further west. Although observed vertical trends in detrital minerals and geographic patterns in elemental abundances agree with the accepted view of a prograding delta complex during Late Devonian time, geographically-local, time restricted depositional processes influenced elemental percentages in subsets of the wells and the stratigraphic intervals studied. The black shales of lower Huron age do not represent simply a return of depositional conditions present in the earlier Rhinestreet time; nor do the gray shales of the Ohio Shale represent the same environmental conditions as the Big White Slate.

Hohn, M.E.; Neal, D.W.; Renton, J.J.

1980-04-01T23:59:59.000Z

90

Fractured gas reservoirs in the Devonian shale of the Illinois and Appalachian basins  

SciTech Connect (OSTI)

The Devonian and Lower Mississippian black shale sequence of Kentucky includes the New Albany Shale of Illinois basin and the Ohio Shale of the Appalachian basin. Fractured reservoirs in the Ohio Shale contain a major gas resource, but have not been so prolific in the New Albany Shale. The authors propose two models of fractured shale reservoirs in both the Illinois and the Appalachian basins, to be tested with gas production data. (1) Where reactivated basement faults have propagated to the surface, the lack of an effective seal has prevented the development of overpressure. The resulting fracture system is entirely tectonic is origin, and served mainly as a conduit for gas migration from the basin to the surface. Gas accumulations in such reservoirs typically are small and underpressured. (2) Where basement faults have been reactivated but have not reached the surface, a seal on the fractured reservoir is preserved. In areas where thermal maturity has been adequate, overpressuring due to gas generation resulted in a major extension of the fracture system, as well as enhanced gas compression and adsorption. Such gas accumulations are relatively large. Original overpressuring has been largely lost, due both to natural depletion and to uncontrolled production. The relative thermal immaturity of the Illinois basin accounts for the scarcity of the second type of fractured reservoir and the small magnitude of the New Albany Shale gas resource.

Hamilton-Smith, T.; Walker, D.; Nuttall, B. (Kentucky Geological Survey, Lexington (United States))

1991-08-01T23:59:59.000Z

91

Late-Middle to Late Devonian (Givetian-Famennian) tectonic and stratigraphic history of central Kentucky  

SciTech Connect (OSTI)

Earliest Givetian deposition in central Kentucky is represented in upper parts of the Boyle and Sellersburg formations and reflects marginal-marine to shallow-marine carbonate deposition at the end of the second tectophase of the Acadian orogeny. Inception of the third tectophase of the Acadian orogeny in the area is reflected by a disconformity or angular unconformity between the Boyle and New Albany formations, by reactivation of faults on the Kentucky river and related fault zones, and by concurrent graben formation. Succeeding late Givetian deposition is represented by the equivalent Portwood and Blocher members of the New Albany. The Portwood represents localized deposition of dolomitic breccias and black shales in grabens and half grabens, paleogeographically manifest as a series of restricted coastal lagoons and estuaries in central and east-central Kentucky. In contrast, dolomitic, Blocher black shales in west-central kentucky, beyond the effects of faulting, reflect more open, platform-lagoonal conditions. Both units are carbonate rick, contain a sparse benthic fauna, and had local sources of sediment. By latest Givetian or earliest Frasnian, local basins were largely filed, and when local sediment sources were inundated by transgression, sediment starvation, represented by a major lag zone or bone bed, ensued throughout central Kentucky, while black- and gray-shale deposition continued in deeper parts of the Illinois and Appalachian basins. During the Frasnian and early Famennian, as subsidence and transgression continued, deeper water gray- and black-shale units from the Appalachian and Illinois basins slowly onlapped the Cincinnati Arch area of central Kentucky; black shales in these units are fissile and lack both carbonates and benthic fauna. At the Devonian-Mississippian transition, however, a locally developed unconformity and structurally related erosion probably reflect inception of the fourth and final tectophase of the Acadian orogeny.

Ettensohn, F.R. (Univ. of Kentucky, Lexington, KY (United States). Dept. of Geological Sciences); Barnett, S.F. (Bryan Coll., Dayton, TN (United States)); Norby, R.D. (Illinois State Geological Survey, Champaign, IL (United States))

1994-04-01T23:59:59.000Z

92

Organic-matter preservation in Chattanooga Shale: revised Late Devonian correlations, Kentucky and Tennessee  

SciTech Connect (OSTI)

Continued interest in the carbon-rich shale of Devonian and Mississippian age in Kentucky is reflected by intensive leasing and drilling to evaluate the potential reserves of oil shale. Thicker accumulations of shale suitable for surface extraction lie along the flanks of the Cincinnati arch in both the Illinois and Appalachian basins. The shale tends to thin across the Cincinnati arch by an order of magnitude (100 versus 10 m, 330 versus 33 ft), and individual units disappear entirely. Key beds have been used with mixed success in tracing these changes. Recognition of these key beds in cores provided by a recently completed 70-core drilling program in and near the outcrop is the basis for revising earlier suggested correlations. One key bed, marked by the occurrence of the alga. Foerstia (Protosalvinia), occurs in the lower part of the lower (Huron) member of the Ohio Shale in the Appalachian basin. The Huron Member is overlain by a lithostratigraphic marker, the Three Lick Bed. The Foerstia Zone has been traced in core and outcrop to the upper part of the uppermost (Clegg Creek) member of the New Albany Shale in the Illinois basin. Discovery in this widespread continuous biostratigraphic marker at the top of the upper (Gassaway) member of the Chattanooga Shale near the designated reference section in Dekalb County, Tennessee, suggests that the Three Lick Bed of the Ohio Shales does not correlate with the unit of the Gassaway Member of the Chattanooga Shale as thought. Field relations indicate that the Three Lick Bed is absent by nondeposition, and starved-basin conditions prevailed into Early Mississippian time in this part of Tennessee.

Kepferle, R.C.; Pollock, J.D.; Barron, L.S.

1983-03-01T23:59:59.000Z

93

Detailed gravity survey over a known carbonate reef (Devonian) in Williston basin  

SciTech Connect (OSTI)

A detailed gravity study, conducted over the Shell Golden carbonate reef located in the Winnipegosis Formation (Devonian) of the Williston basin in north-central North Dakota, indicates a massive carbonate platform with several interconnected vertical accumulations, perhaps pinnacle in nature, from this platform. This reef is found at a depth of about 2400 m (8000 ft). Because elevations and north-south positions were surveyed to /+-/3 cm (0.1 ft) and /+-/ 1 (3.3 ft), respectively, an accuracy of 0.01 mgal was obtained. Five profiles were made: three lines running east-west and two lines running north-south, forming a grid pattern over the reef. The distance between each line was 1.6 km (1.0 mi) with gravity-station spacing along each line being 0.4 km (0.25 mi). The Golden reef and most reefs of this nature throughout the North Dakota portion of the Williston basin have been interpreted to be isolated pinnacles with physical dimensions about 60-75 m (200-250 ft) thick and 0.8 km (0.5 mi) in basal diameter. However, analysis of the residual Bouguer gravity anomalies (0.2-0.5 mgal) obtained from this study indicates this reef is more complex than previously thought. The maximum thicknesses of the complex are on the order of 120-185 m (400-600 ft) with compaction anticlines also contributing to the total gravity anomaly. The modeled reef complex extends in a northeast-southwest direction and probably extends beyond the study area along that line.

Braun, S.M.

1988-07-01T23:59:59.000Z

94

Coordinated study of the Devonian black shale in the Illinois Basin: Illinois, Indiana, and western Kentucky. Final report  

SciTech Connect (OSTI)

An evaluation of the resource potential of the Devonian shales, called the Eastern Gas Shales Project (EGSP) was begun. A study of the stratigraphy, structure, composition, and gas content of the Devonian shale in the Illinois Basin was undertaken by the State Geological Surveys of Illinois, Indiana, and Kentucky, under contract to the U.S. DOE as a part of the EGSP. Certain additional data were also developed by other research organizations (including Monsanto Research Corporation-Mound Facility and Battelle-Columbus Laboratory) on cores taken from the Illinois Basin. This report, an overview of geological data on the Illinois basin and interpretations of this data resulting from the EGSP, highlights areas of potential interest as exploration targets for possible natural gas resources in the Devonian shale of the basin. The information in this report was compiled during the EGSP from open file data available at the three State Geological surveys and from new data developed on cores taken by the DOE from the basin specifically for the EGSP. The organically richest shale is found in southeastern Illinois and in most of the Indiana and Kentucky portions of the Illinois Basin. The organic-rich shales in the New Albany are thickest near the center of the basin in southeastern Illinois, southwestern Indiana, and adjacent parts of Kentucky portions of the Illinois Basin. The organic-rich shales in the New Albany are thickest near the center of the basin in southeastern Illinois, southwestern Indiana, and adjacent parts of Kentucky. Natural fractures in the shale may aid in collecting gas from a large volume of shale. These fractures may be more abundant and interconnected to a greater degree in the vicinity of major faults. Major faults along the Rough Creek Lineament and Wabash Valley Fault System cross the deeper part of the basin.

Lineback, J.A.

1980-12-31T23:59:59.000Z

95

UTICA 4, NEW YORK COFIPOR~TION  

Office of Legacy Management (LM)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr May Jun Jul(Summary) "ofEarlyEnergyDepartment ofDepartment ofof EnergyYou$0.C. 20545 OCTTO: FILEWAWINQTON, 0. C.JournalDROf

96

Bakken and other Devonian-Mississippian petroleum source rocks, northern Rocky Mtns.-Williston basin: Depositional and burial history and maturity estimations  

SciTech Connect (OSTI)

The three-member Devonian-Mississippian Bakken-Exshaw organic-rich shaly facies is widely distributed in the northern U.S. and southern Canadian Cordillera. Equivalent facies are also present as far south as Utah and Nevada. Paleogeographically, these rocks thin markedly or pinchout to the west approximately along the Devonian-Mississippian carbonate reef-mound belt of the Cordilleran shelf margin. Although these rocks reach maximum organic richness approximately at the Devonian-Carboniferous transition, similar but somewhat less organic-rich Bakken-like beds are also present in underlying Upper Devonian and overlying Lower Carboniferous carbonate depositional cycles. At least ten cycles are identified in the underlying Duperow and Jefferson Formations, characterized by basal organic-rich Bakken-like shale or shaly carbonate that grades upward into carbonate mound or reefal beds, overlain by evaporite or solution breccia. Cycles in the overlying Lodgepole and Mission Canyon Formations, as many as 10-12 in number, are similar except that the carbonates are composed of algal-oolith, crinoid, or mixed skeletal beds, and end-cycle evaporitic units are less prevalent in the lower cycles. These dark shaly beds are the most important source of hydrocarbon reserves in Montana and the Williston basin. Maximum net thickness of the Devonian-Mississippian organic-rich facies is in the Williston basin. However, variable thicknesses of these potential source rocks is present in parts of Montana as far west as the thrust belt. Burial history studies suggest that in some areas these rocks are probably thermally immature. However, in much of the area original burial depths are sufficient for them to reach the thermally mature stage, and therefore are of importance to further exploration efforts in the Devonian-Mississippian Madison-Duperow-Jefferson Formations.

Peterson, J.A. [Univ. of Montana, Missoula, MT (United States)

1996-06-01T23:59:59.000Z

97

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

CO{sub 2} emissions from the combustion of fossil fuels have been linked to global climate change. Proposed carbon management technologies include geologic sequestration of CO{sub 2}. A possible, but untested, sequestration strategy is to inject CO{sub 2} into organic-rich shales. Devonian black shales underlie approximately two-thirds of Kentucky and are thicker and deeper in the Illinois and Appalachian Basin portions of Kentucky than in central Kentucky. The Devonian black shales serve as both the source and trap for large quantities of natural gas; total gas in place for the shales in Kentucky is estimated to be between 63 and 112 trillion cubic feet. Most of this natural gas is adsorbed on clay and kerogen surfaces, analogous to methane storage in coal beds. In coals, it has been demonstrated that CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. The concept that black, organic-rich Devonian shales could serve as a significant geologic sink for CO{sub 2} is the subject of current research. To accomplish this investigation, drill cuttings and cores were selected from the Kentucky Geological Survey Well Sample and Core Library. Methane and carbon dioxide adsorption analyses are being performed to determine the gas-storage potential of the shale and to identify shale facies with the most sequestration potential. In addition, sidewall core samples are being acquired to investigate specific black-shale facies, their potential CO{sub 2} uptake, and the resulting displacement of methane. Advanced logging techniques (elemental capture spectroscopy) are being investigated for possible correlations between adsorption capacity and geophysical log measurements. Initial estimates indicate a sequestration capacity of 5.3 billion tons CO{sub 2} in the Lower Huron Member of the Ohio shale in parts of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker portions of the Devonian shales in Kentucky. Should the black shales of Kentucky prove to be a viable geologic sink for CO{sub 2}, their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2003-07-28T23:59:59.000Z

98

The use of pre- and post-stimulation well test analysis in the evaluation of stimulation effectiveness in the Devonian Shales of the Appalachian Basin  

E-Print Network [OSTI]

gas wells throughout the Appalachian Basin. The analysis of pre-stimulation well tests from four wells in Pike County, KY illustrates the practical difficulties in obtaining analyzable data from Devonian Shale wells. Fig. 1 shows the location... and requires that the flow periods prior to shut-in be even longer. The Martin 1 well located in Martin County, KY illustrates the problem of an insufficient flow period in a more typical Devonian Shale well test. The Martin 1 well was studied as part...

Lancaster, David Earl

1988-01-01T23:59:59.000Z

99

Assessment of Factors Influencing Effective CO{sub 2} Storage Capacity and Injectivity in Eastern Gas Shales  

SciTech Connect (OSTI)

Building upon advances in technology, production of natural gas from organic-rich shales is rapidly developing as a major hydrocarbon supply option in North America and around the world. The same technology advances that have facilitated this revolution - dense well spacing, horizontal drilling, and hydraulic fracturing - may help to facilitate enhanced gas recovery (EGR) and carbon dioxide (CO{sub 2}) storage in these formations. The potential storage of CO {sub 2} in shales is attracting increasing interest, especially in Appalachian Basin states that have extensive shale deposits, but limited CO{sub 2} storage capacity in conventional reservoirs. The goal of this cooperative research project was to build upon previous and on-going work to assess key factors that could influence effective EGR, CO{sub 2} storage capacity, and injectivity in selected Eastern gas shales, including the Devonian Marcellus Shale, the Devonian Ohio Shale, the Ordovician Utica and Point Pleasant shale and equivalent formations, and the late Devonian-age Antrim Shale. The project had the following objectives: (1) Analyze and synthesize geologic information and reservoir data through collaboration with selected State geological surveys, universities, and oil and gas operators; (2) improve reservoir models to perform reservoir simulations to better understand the shale characteristics that impact EGR, storage capacity and CO{sub 2} injectivity in the targeted shales; (3) Analyze results of a targeted, highly monitored, small-scale CO{sub 2} injection test and incorporate into ongoing characterization and simulation work; (4) Test and model a smart particle early warning concept that can potentially be used to inject water with uniquely labeled particles before the start of CO{sub 2} injection; (5) Identify and evaluate potential constraints to economic CO{sub 2} storage in gas shales, and propose development approaches that overcome these constraints; and (6) Complete new basin-level characterizations for the CO{sub 2} storage capacity and injectivity potential of the targeted eastern shales. In total, these Eastern gas shales cover an area of over 116 million acres, may contain an estimated 6,000 trillion cubic feet (Tcf) of gas in place, and have a maximum theoretical storage capacity of over 600 million metric tons. Not all of this gas in-place will be recoverable, and economics will further limit how much will be economic to produce using EGR techniques with CO{sub 2} injection. Reservoir models were developed and simulations were conducted to characterize the potential for both CO{sub 2} storage and EGR for the target gas shale formations. Based on that, engineering costing and cash flow analyses were used to estimate economic potential based on future natural gas prices and possible financial incentives. The objective was to assume that EGR and CO{sub 2} storage activities would commence consistent with the historical development practices. Alternative CO{sub 2} injection/EGR scenarios were considered and compared to well production without CO{sub 2} injection. These simulations were conducted for specific, defined model areas in each shale gas play. The resulting outputs were estimated recovery per typical well (per 80 acres), and the estimated CO{sub 2} that would be injected and remain in the reservoir (i.e., not produced), and thus ultimately assumed to be stored. The application of this approach aggregated to the entire area of the four shale gas plays concluded that they contain nearly 1,300 Tcf of both primary production and EGR potential, of which an estimated 460 Tcf could be economic to produce with reasonable gas prices and/or modest incentives. This could facilitate the storage of nearly 50 Gt of CO{sub 2} in the Marcellus, Utica, Antrim, and Devonian Ohio shales.

Godec, Michael

2013-06-30T23:59:59.000Z

100

Assessment of environmental health and safety issues associated with the commercialization of unconventional gas recovery: Devonian shale  

SciTech Connect (OSTI)

The purpose of this study is to identify and examine potential public health and safety issues and the potential environmental impacts from recovery of natural gas from Devonian age shale. This document will serve as background data and information for planners within the government to assist in development of our new energy technologies in a timely and environmentally sound manner. This report describes the resource and the DOE eastern gas shales project in Section 2. Section 3 describes the new and developing recovery technologies associated with Devonian shale. An assessment of the environment, health and safety impacts associated with a typical fields is presented in Section 4. The typical field for this assessment occupies ten square miles and is developed on a 40-acre spacing (that is, there is a well in each 40-acre grid). This field thus has a total of 160 wells. Finally, Section 5 presents the conclusions and recommendations. A reference list is provided to give a greater plant. Based on the estimated plant cost and the various cases of operating income, an economic analysis was performed employing a profitability index criterion of discounted cash flow to determine an interest rate of return on the plant investment.

Not Available

1981-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
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We encourage you to perform a real-time search of NLEBeta
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101

Bibliography of the paleontology and paleoecology of the Devonian-Mississippian black-shale sequence in North America  

SciTech Connect (OSTI)

The Devonian-Mississippian black-shale sequence is one of the most prominent and well-known stratigraphic horizons in the Paleozoic of the United States, yet the paleontology and its paleoecologic and paleoenvironmental implications are poorly known. This is in larger part related to the scarcity of fossils preserved in the shale - in terms of both diversity and abundance. Nonetheless, that biota which is preserved is well-known and much described, but there is little synthesis of this data. The first step in such a synthesis is the compilation of an inclusive bibliography such as this one. This bibliography contains 1193 entries covering all the major works dealing with Devonian-Mississippian black-shale paleontology and paleoecology in North America. Articles dealing with areas of peripheral interest, such as paleogeography, paleoclimatology, ocean circulation and chemistry, and modern analogues, are also cited. In the index, the various genera, taxonomic groups, and other general topics are cross-referenced to the cited articles. It is hoped that this compilation will aid in the synthesis of paleontologic and paleoecologic data toward a better understanding of these unique rocks and their role as a source of energy.

Barron, L.S.; Ettensohn, F.R.

1980-06-01T23:59:59.000Z

102

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

Devonian gas shales underlie approximately two-thirds of Kentucky. In the shale, natural gas is adsorbed on clay and kerogen surfaces. This is analogous to methane storage in coal beds, where CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. Drill cuttings from the Kentucky Geological Survey Well Sample and Core Library were sampled to determine CO{sub 2} and CH{sub 4} adsorption isotherms. Sidewall core samples were acquired to investigate CO{sub 2} displacement of methane. An elemental capture spectroscopy log was acquired to investigate possible correlations between adsorption capacity and mineralogy. Average random vitrinite reflectance data range from 0.78 to 1.59 (upper oil to wet gas and condensate hydrocarbon maturity range). Total organic content determined from acid-washed samples ranges from 0.69 to 14 percent. CO{sub 2} adsorption capacities at 400 psi range from a low of 14 scf/ton in less organic-rich zones to more than 136 scf/ton. There is a direct correlation between measured total organic carbon content and the adsorptive capacity of the shale; CO{sub 2} adsorption capacity increases with increasing organic carbon content. Initial estimates based on these data indicate a sequestration capacity of 5.3 billion tons of CO{sub 2} in the Lower Huron Member of the Ohio Shale of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker parts of the Devonian shales in Kentucky. Should the black shales of Kentucky prove to be a viable geologic sink for CO{sub 2}, their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2005-04-26T23:59:59.000Z

103

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

Devonian gas shales underlie approximately two-thirds of Kentucky. In the shale, natural gas is adsorbed on clay and kerogen surfaces. This is analogous to methane storage in coal beds, where CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. Drill cuttings from the Kentucky Geological Survey Well Sample and Core Library were sampled to determine CO{sub 2} and CH{sub 4} adsorption isotherms. Sidewall core samples were acquired to investigate CO{sub 2} displacement of methane. An elemental capture spectroscopy log was acquired to investigate possible correlations between adsorption capacity and mineralogy. Average random vitrinite reflectance data range from 0.78 to 1.59 (upper oil to wet gas and condensate hydrocarbon maturity range). Total organic content determined from acid-washed samples ranges from 0.69 to 14 percent. CO{sub 2} adsorption capacities at 400 psi range from a low of 14 scf/ton in less organic-rich zones to more than 136 scf/ton. There is a direct correlation between measured total organic carbon content and the adsorptive capacity of the shale; CO{sub 2} adsorption capacity increases with increasing organic carbon content. Initial estimates based on these data indicate a sequestration capacity of 5.3 billion tons of CO{sub 2} in the Lower Huron Member of the Ohio Shale of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker parts of the Devonian shales in Kentucky. Should the black shales of Kentucky prove to be a viable geologic sink for CO{sub 2}, their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2005-07-29T23:59:59.000Z

104

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

Devonian gas shales underlie approximately two-thirds of Kentucky. In the shale, natural gas is adsorbed on clay and kerogen surfaces. This is analogous to methane storage in coal beds, where CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. Drill cuttings from the Kentucky Geological Survey Well Sample and Core Library are being sampled to collect CO{sub 2} adsorption isotherms. Sidewall core samples have been acquired to investigate CO{sub 2} displacement of methane. An elemental capture spectroscopy log has been acquired to investigate possible correlations between adsorption capacity and mineralogy. Average random vitrinite reflectance data range from 0.78 to 1.59 (upper oil to wet gas and condensate hydrocarbon maturity range). Total organic content determined from acid-washed samples ranges from 0.69 to 4.62 percent. CO{sub 2} adsorption capacities at 400 psi range from a low of 19 scf/ton in less organic-rich zones to more than 86 scf/ton in the Lower Huron Member of the shale. Initial estimates based on these data indicate a sequestration capacity of 5.3 billion tons of CO{sub 2} in the Lower Huron Member of the Ohio Shale of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker parts of the Devonian shales in Kentucky. Should the black shales of Kentucky prove to be a viable geologic sink for CO{sub 2}, their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2004-08-01T23:59:59.000Z

105

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

Devonian gas shales underlie approximately two-thirds of Kentucky. In the shale, natural gas is adsorbed on clay and kerogen surfaces. This is analogous to methane storage in coal beds, where CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. Drill cuttings from the Kentucky Geological Survey Well Sample and Core Library were sampled to determine CO{sub 2} and CH{sub 4} adsorption isotherms. Sidewall core samples were acquired to investigate CO{sub 2} displacement of methane. An elemental capture spectroscopy log was acquired to investigate possible correlations between adsorption capacity and mineralogy. Average random vitrinite reflectance data range from 0.78 to 1.59 (upper oil to wet gas and condensate hydrocarbon maturity range). Total organic content determined from acid-washed samples ranges from 0.69 to 14 percent. CO{sub 2} adsorption capacities at 400 psi range from a low of 14 scf/ton in less organic-rich zones to more than 136 scf/ton. Initial estimates based on these data indicate a sequestration capacity of 5.3 billion tons of CO{sub 2} in the Lower Huron Member of the Ohio Shale of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker parts of the Devonian shales in Kentucky. Should the black shales of Kentucky prove to be a viable geologic sink for CO{sub 2}, their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2005-01-01T23:59:59.000Z

106

ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS PRODUCTION  

SciTech Connect (OSTI)

Devonian gas shales underlie approximately two-thirds of Kentucky. In the shale, natural gas is adsorbed on clay and kerogen surfaces. This is analogous to methane storage in coal beds, where CO{sub 2} is preferentially adsorbed, displacing methane. Black shales may similarly desorb methane in the presence of CO{sub 2}. Drill cuttings from the Kentucky Geological Survey Well Sample and Core Library were sampled to determine CO{sub 2} and CH{sub 4} adsorption isotherms. Sidewall core samples were acquired to investigate CO{sub 2} displacement of methane. An elemental capture spectroscopy log was acquired to investigate possible correlations between adsorption capacity and mineralogy. Average random vitrinite reflectance data range from 0.78 to 1.59 (upper oil to wet gas and condensate hydrocarbon maturity range). Total organic content determined from acid-washed samples ranges from 0.69 to 14 percent. CO{sub 2} adsorption capacities at 400 psi range from a low of 14 scf/ton in less organic-rich zones to more than 136 scf/ton. There is a direct correlation between measured total organic carbon content and the adsorptive capacity of the shale; CO{sub 2} adsorption capacity increases with increasing organic carbon content. Initial estimates based on these data indicate a sequestration capacity of 5.3 billion tons of CO{sub 2} in the Lower Huron Member of the Ohio Shale of eastern Kentucky and as much as 28 billion tons total in the deeper and thicker parts of the Devonian shales in Kentucky. Should the black shales of Kentucky prove to be a viable geologic sink for CO{sub 2}, their extensive occurrence in Paleozoic basins across North America would make them an attractive regional target for economic CO{sub 2} storage and enhanced natural gas production.

Brandon C. Nuttall

2005-01-28T23:59:59.000Z

107

Stratigraphy and organic petrography of Mississippian and Devonian oil shale at the Means Project, East-Central Kentucky  

SciTech Connect (OSTI)

The Means Oil Shale Project is under consideration for financial assistance by the US Synthetic Fuels Corporation. The project site is located in southern Montgomery County, about 45 miles east of Lexington, Kentucky. In the site area the Devonian Ohio Shale and the Mississippian Sunbury Shale are under study; these oil shales were deposited in the Appalachian Basin. The objective of the Means Project is to mine, using open pit methods, an ore zone which includes the Sunbury and upper Cleveland and which excludes the Bedford interburden. The thick lower grade oil shale below this ore zone renders the higher grade shale at the base of the Huron commercially unattractive. The oil shale at Means has been classified as a marinite, an oil shale containing abundant alginite of marine origin. Lamalginite is the dominant liptinite and comprises small, unicellular alginite with weak to moderate fluorescence at low rank and a distinctive lamellar form. Telalginite, derived from large colonial or thick-walled, unicellular algae, is common in several stratigraphic intervals.

Solomon, B.J.; Hutton, A.C.; Henstridge, D.A.; Ivanac, J.F.

1985-02-01T23:59:59.000Z

108

Paleoecology of the Devonian-Mississippian black-shale sequence in eastern Kentucky with an atlas of some common fossils  

SciTech Connect (OSTI)

The Devonian-Mississippian black-shale sequence of eastern North America is a distinctive stratigraphic interval generally characterized by low clastic influx, high organic production in the water column, anaerobic bottom conditions, and the relative absence of fossil evidence for biologic activity. The laminated black shales which constitute most of the black-shale sequence are broken by two major sequences of interbedded greenish-gray, clayey shales which contain bioturbation and pyritized micromorph invertebrates. The black shales contain abundant evidence of life from upper parts of the water column such as fish fossils, conodonts, algae and other phytoplankton; however, there is a lack of evidence of benthic life. The rare brachiopods, crinoids, and molluscs that occur in the black shales were probably epiplanktic. A significant physical distinction between the environment in which the black sediments were deposited and that in which the greenish-gray sediments were deposited was the level of dissolved oxygen. The laminated black shales point to anaerobic conditions and the bioturbated greenish-gray shales suggest dysaerobic to marginally aerobic-dysaerobic conditions. A paleoenvironmental model in which quasi-estuarine circulation compliments and enhances the effect of a stratified water column can account for both depletion of dissolved oxygen in the bottom environments and the absence of oxygen replenishment during black-shale deposition. Periods of abundant clastic influx from fluvial environments to the east probably account for the abundance of clays in the greenish-gray shale as well as the small amounts of oxygen necessary to support the depauparate, opportunistic, benthic faunas found there. These pulses of greenish-gray clastics were short-lived and eventually were replaced by anaerobic conditions and low rates of clastic sedimentation which characterized most of black-shale deposition.

Barron, L.S.; Ettensohn, F.R.

1981-04-01T23:59:59.000Z

109

Sedimentology, petrology, and gas potential of the Brallier Formation: upper Devonian turbidite facies of the Central and Southern Appalachians  

SciTech Connect (OSTI)

The Upper Devonian Brallier Formation of the central and southern Appalachian basin is a regressive sequence of siltstone turbidites interbedded with mudstones, claystones, and shales. It reaches 1000 meters in thickness and overlies basinal mudrocks and underlies deltaic sandstones and mudrocks. Facies and paleocurrent analyses indicate differences between the depositional system of the Brallier Formation and those of modern submarine fans and ancient Alpine flysch-type sequences. The Brallier system is of finer grain size and lower flow intensity. In addition, the stratigraphic transition from turbidites to deltaic sediments is gradual and differs in its facies succession from the deposits of the proximal parts of modern submarine fans. Such features as massive and pebbly sandstones, conglomerates, debris flows, and massive slump structures are absent from this transition. Paleocurrents are uniformly to the west at right angles to basin isopach, which is atypical of ancient turbidite systems. This suggests that turbidity currents had multiple point sources. The petrography and paleocurrents of the Brallier Formation indicate an eastern source of sedimentary and low-grade metasedimentary rocks with modern relief and rainfall. The depositional system of the Brallier Formation is interpreted as a series of small ephemeral turbidite lobes of low flow intensity which coalesced in time to produce a laterally extensive wedge. The lobes were fed by deltas rather than submarine canyons or upper fan channel systems. This study shows that the present-day turbidite facies model, based mainly on modern submarine fans and ancient Alpine flysch-type sequences, does not adequately describe prodeltaic turbidite systems such as the Brallier Formation. Thickly bedded siltstone bundles are common features of the Brallier Formation and are probably its best gas reservoir facies, especially when fracture porosity is well developed.

Lundegard, P.D.; Samuels, N.D.; Pryor, W.A.

1980-03-01T23:59:59.000Z

110

Orientation of tectonic stresses in central Kentucky during U. Devonian/L. Mississippian times: Evidence from quartz veins (after gypsum) in NE-trending, systematic joints in shales  

SciTech Connect (OSTI)

Quartz replacing fibrous gypsum and anhydrite pseudomorphically (QAS; quartz after sulfate''), and preserving characteristic crack-seal'' and chickenwire'' textures, occurs in extensional veins at four locations in central KY. The veins occupy a systematic set of NE-SW-trending, vertical joints within the essentially flat-lying shales of the Renfro Member of the Mississippian Borden Formation and the Late Devonian New Albany Shale. The four QAS occurrences discovered to date are located northeast of the Borden Front. At one site in the New Albany Shale, QAS veins show clear evidence of penecontemporaneous deformation. It is proposed that at all QAS locations, gypsum precipitated in incipient joints before complete lithification of the sediment, and grew perpendicular to the fractures to form extensional veins in the soft but firm muds. The orientations of the joints now marked by QAS veins are broadly consistent with regional patterns of NE-SW-trending systematic joints and lineaments in southern IN and in central and eastern KY. These systematic fracture patterns do not correspond directly to known basement faults or rift systems, although they are consistent with modern stress directions in eastern and western KY, measured in situ in wells and by earthquake fault-plane solutions. It is proposed that this systematic trend marks the regional tectonic stress pattern characteristic of southern IN and central and eastern KY at, and since the Late Devonian. The evidence of penecontemporaneous sedimentary deformation in joints of U. Devonian age, marked and preserved by quartz replacement of early gypsum, is sufficient to show that while the systematic NE-trending joint set in KY may also be modern it is not uniquely so.

Grover, J.; Dupuis-Nouille, E.M. (Univ. of Cincinnati, Cincinnati, OH (United States). Dept. of Geology)

1992-01-01T23:59:59.000Z

111

A resource evaluation of the Bakken Formation (Upper Devonian and Lower Mississippian) continuous oil accumulation, Williston Basin, North Dakota and Montana  

SciTech Connect (OSTI)

The Upper Devonian and Lower Mississippian Bakken Formation in the United States portion of the Williston Basin is both the source and the reservoir for a continuous oil accumulation -- in effect a single very large field -- underlying approximately 17,800 mi{sup 2} (46,100 km{sup 2}) of North Dakota and Montana. Within this area, the Bakken Formation continuous oil accumulation is not significantly influenced by the water column and cannot be analyzed in terms of conventional, discrete fields. Rather, the continuous accumulation can be envisioned as a collection of oil-charged cells, virtually all of which are capable of producing some oil, but which vary significantly in their production characteristics. Better well-performance statistics are linked regionally to higher levels of thermal maturity and to lower levels of reservoir heterogeneity. Although portions of the Bakken Formation continuous oil accumulation have reached a mature stage of development, the accumulation as a whole is far from depleted.

Schmoker, J.W. [Geological Survey, Denver, CO (United States)

1996-01-01T23:59:59.000Z

112

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 (OSTI)

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.

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

1983-01-01T23:59:59.000Z

113

Machel, H.G., Buschkuehle, B.E. and Michael, K., 2001, Squeegee flow in Devonian carbonate aquifers in Alberta, Canada. In: Cidu, R. (ed.), Water-Rock Interaction, Vol. 1. Proceedings of the Tenth International Symposium on Water-Rock-Interaction WRI-  

E-Print Network [OSTI]

in thickness. Across much of the basin the four Devonian aquifers, which contain oil, sweet and sour gas reservoirs, are interbedded with marly and evaporitic aquitards, and are confined by tight evaporites

Machel, Hans

114

Modular CHP System for Utica College: Design Specification, March...  

Broader source: Energy.gov (indexed) [DOE]

install and interconnect at the College with minimal time and engineering needs. uticachp.pdf More Documents & Publications Commissioning of CHP Systems - White Paper, April...

115

Utica Energy LLC formerly Algoma Ethanol | Open Energy Information  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home5b9fcbce19 NoPublic Utilities Address: 160 East 300 South Place: Salt Lake City, Utah Zip: 84111Jump to: navigation,

116

Rock-eval data relating to oil-source potential of shales of New Albany group (Devonian-Mississippian) in Illinois basin  

SciTech Connect (OSTI)

Only limited data on petroleum source rock potential of New Albany Group (Devonian-Mississippian) shales have been reported, with the exception of vitrinite reflectance and some petrographic analyses. The New Albany Group contains the thickest and most widespread continuous black shale beds in the Illinois basin. The New Albany extends from northwestern Illinois to southwestern Indiana and western Kentucky and is thought to have played a major role in petroleum generation throughout the basin. In this study, Rock-Eval pyrolysis was used to measure the petroleum-generative potential and production index of the shale. Seven geochemical logs, based on 143 core samples from across the basin, and a production index map, based on a total of 252 samples (cuttings and cores) in Illinois, were generated. Systematic variations of petroleum-generative potential of the shale were observed. The variations are related to the differences in shale lithofacies, depth, and geographic location. The upper portion of the New Albany - the Hannibal and Saverton Shales - has the lowest oil-generative potential. The Grassy Creek, Sweetland Creek, and other stratigraphically lower shales of the New Albany Group generally have good oil-generative potential. However, samples from the Hicks dome area of extreme southern Illinois are overmature and have no oil-generative potential. Source rocks that have both good oil-generative potential (> 6 kg hydrocarbons per ton of rock) and a higher production index (> 0.09) are generally located at depths of 2,500-5,300 ft.

Chou, Mei-In M.; Dickerson, D.R.; Sargent, M.L. (Illinois State Geological Survey, Champaign (USA))

1988-08-01T23:59:59.000Z

117

Recognition and delineation of Paleokarst zones by the use of wireline logs in the bitumen-saturated upper Devonian Grosmont formation of Northeastern Alberta, Canada  

SciTech Connect (OSTI)

The Upper Devonian Grosmont Formation in northeastern Alberta, Canada, is a shallow-marine carbonate platform complex that was subaerially exposed for hundreds of millions of years between the Mississippian(?) and Cretaceous. During this lengthy exposure period, an extensive karst system developed that is characterized by an irregular erosional surface, meter-size (several feet) dissolution cavities, collapse breccias, sinkholes, paleosols, and fractures. The karsted Grosmont Formation, which contains giant reserves of bitumen, sub-crops beneath Cretaceous clastic sediments of the giant Athabasca tar sands deposit. The paleokarst in the Grosmont Formation can be recognized on wireline logs in relatively nonargillaceous carbonate intervals (<30 API units on the gamma-ray log) as excursions of the caliper log, off-scale neutron-density porosity readings, and severe cycle skipping of the acoustic log. The paleokarst is more prevalent in the upper units of the Grosmont Formation, and the effects of karstification decrease toward stratigraphically older and deeper units. The paleokarst usually occurs within 35 m (115 ft) of the erosional surface. The reservoir properties of the Grosmont Formation (e.g., thickness, porosity, permeability, and seal effectiveness) are significantly influenced by karstification. Depending upon the location, karstification has either benefited or degraded the reservoir characteristics. Benefits include porosity values greater than 40% (up to 100% in caverns) and permeability values of 30,000 md in severely fractured intervals. Detrimental reservoir characteristics include erosion, porosity and permeability reduction, and seal ineffectiveness.

Dembicki, E.A.; Machel, H.G. [Univ. of Alberta, Edmonton, Alberta (Canada)

1996-05-01T23:59:59.000Z

118

Observed Impacts of Marcellus Shale Drilling on  

E-Print Network [OSTI]

Pollution Prevention #12;Site Restoration Mandatory stockpiling of topsoil at time of well pad construction Department of City & Regional Planning Cornell University #12;Why Bradford County, PA? Small Industrial Towns) #12;Typical Well Pad ·Hydraulic Fracturing Phase #12;Storm Water Pollution Prevention Well pads

119

Marcellus Shale Advisory Commission Report Summary  

E-Print Network [OSTI]

bodies of water from 100 to 300 feet. Increase setback distance from private water wells from 200 actions. Expand public disclosure and information through enhanced well production and completion,000. Double daily penalties from $1,000 to $2,000 a day. Make penalties for criminal violations consistent

Boyer, Elizabeth W.

120

Potential Ecological Effects of Marcellus Shale Activities  

E-Print Network [OSTI]

· Timber · Agriculture · Oil & Gas · Iron · Limestone · Water #12;Conceptual Model with Fresh water usage, management, recycling · Air fugitive emissions, diesel engines, gas is cleaner as fuel compared to coal & oil · Offgasing from · condensate and · storage tanks · Vs. oil and coal #12;Ecological Impacts ­ Chemical Use

Jiang, Huiqiang

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


121

January 20, 2011 Marcellus Shale 101  

E-Print Network [OSTI]

. Will oil shale be viable as well? Oil shale will not be economically viable anytime in the near future

Hardy, Christopher R.

122

Review Meeting Mudrock Systems Research Laboratory  

E-Print Network [OSTI]

:10 ­ 9:40 AM Devonian mudrock pore systems: Bakken, Woodford, New Albany; Reed 9:40 ­ 10:10 AM and Future: Ruppel Paleozoic Mudrock Systems 8:40 ­ 9:10 AM Natural fractures in the Marcellus Shale; Gale 9 properties from 3D seismic data; Zeng 2:30 ­ 3:00 PM Preliminary characterization of the Tuscaloosa shale; Lu

Texas at Austin, University of

123

DOE - Office of Legacy Management -- Utica Drop Forge and Tool Corp - NY 39  

Office of Legacy Management (LM)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr May Jun Jul(Summary) "ofEarlyEnergyDepartment ofDepartment ofof EnergyYou areDowntown Site -Miami - FL 0-01NY

124

DOE - Office of Legacy Management -- Utica Street Warehouse - NY 0-23  

Office of Legacy Management (LM)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr May Jun Jul(Summary) "ofEarlyEnergyDepartment ofDepartment ofof EnergyYou areDowntown Site -Miami - FL 0-01NYStreet Warehouse

125

Autopoietic landscapes : the architectural implications of mining the Marcellus Shale  

E-Print Network [OSTI]

Hydraulic fracturing, a form of natural gas extraction, is a process deeply embedded in the networks of politics, power, economics, energy, infrastructure, and land use. Hydraulic fracturing has become a standard practice ...

Winfield, Catherine (Catherine Anne)

2013-01-01T23:59:59.000Z

126

Water management technologies used by Marcellus Shale Gas Producers.  

SciTech Connect (OSTI)

Natural gas represents an important energy source for the United States. According to the U.S. Department of Energy's (DOE's) Energy Information Administration (EIA), about 22% of the country's energy needs are provided by natural gas. Historically, natural gas was produced from conventional vertical wells drilled into porous hydrocarbon-containing formations. During the past decade, operators have increasingly looked to other unconventional sources of natural gas, such as coal bed methane, tight gas sands, and gas shales.

Veil, J. A.; Environmental Science Division

2010-07-30T23:59:59.000Z

127

A study of natural gas extraction in Marcellus shale .  

E-Print Network [OSTI]

??With the dramatic increases in crude oil prices there has been a need to find reliable energy substitutions. One substitution that has been used in (more)

Boswell, Zachary (Zachary Karol)

2011-01-01T23:59:59.000Z

128

A study of natural gas extraction in Marcellus shale  

E-Print Network [OSTI]

With the dramatic increases in crude oil prices there has been a need to find reliable energy substitutions. One substitution that has been used in the United States is natural gas. However, with the increased use of natural ...

Boswell, Zachary (Zachary Karol)

2011-01-01T23:59:59.000Z

129

Marcellus Shale Drilling and Hydraulic Fracturing; Technicalities and  

E-Print Network [OSTI]

Pipe · Air Rotary Drilling Rig · Hydraulic Rotary Drilling Rig ­ Barite/Bentonite infused drilling muds A "Thumper Truck" #12;Rigging Up #12;Drilling · The Drill String ­ Diesel Powered ­ Drilling Bit ­ Drilling

Jiang, Huiqiang

130

Impacts of Marcellus Shale Development on Municipal Governments in Susquehanna  

E-Print Network [OSTI]

-thirds of the state. The development of this natural gas resource is creating significant eco- nomic opportunities to some. Town- ships, boroughs, and cities are re- sponsible for providing important public services

Boyer, Elizabeth W.

131

Water Treatment System Cleans Marcellus Shale Wastewater | Department of  

Office of Environmental Management (EM)

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132

Water Withdrawals for Development of Marcellus Shale Gas in Pennsylvania  

E-Print Network [OSTI]

is the fracking fluid (also called drilling return wa- ter, drilling wastewater, flowback, or produced- ing (fracking), the portion of water withdrawals related to mining is likely to rise. The information

Boyer, Elizabeth W.

133

NORM Mitigation and Clean Water Recovery from Marcellus Produced...  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

product to be suitable for either beneficial reuse or disposal as nonhazardous waste. We evaluated seven pretreatment processes to remove barium and radium from Design Case-1...

134

NORM Mitigation and Clean Water Recovery from Marcellus Produced Water  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr MayAtmosphericNuclear Security Administration the Contributions and Achievements of Women |hits 21Species. |RPSEA Final Report Report

135

A spider and other arachnids from the Devonian of New York, and reinterpretations of Devonian Araneae  

E-Print Network [OSTI]

. from the Pragian Rhyn ie Cher t of Aberdeenshire , Scot land. T h e descr ipt ion of a n o t h e r fossil assigned to the Araneae , Archaeometal devonica S tormer , 1976, from the Emsian of Alkcn-an-der -Mose l . G e r m a n y , added more evidence... ropod remains from Rhynie , and thus difficult to pho tog raph . Add ing to the prob lems are the cloudiness of the matr ix , o p a q u e inclusions, and the very small size of the specimen, a b o u t 0-85 m m long. In add i t ion to p h o t o g r a p...

Selden, Paul A.; Shear, William A.; Bonamo, Patricia M.

1991-06-01T23:59:59.000Z

136

FACTORS THAT INFLUENCE CIVIC PARTICIPATION IN ECONOMIC DEVELOPMENT PLANNING: TOURISM IN THE VILLAGE OF NORTH UTICA, ILLINOIS  

E-Print Network [OSTI]

Participatory economic development planning has been proposed as a means to address problems associated with more traditional "top-down" planning methods. Purposeful solicitation of participation in development planning ...

Spears, Chaya Riannon

2011-04-26T23:59:59.000Z

137

Modern Devonian shale gas search starting in southwestern Indiana  

SciTech Connect (OSTI)

The New Albany shale of southwestern Indiana is a worthwhile exploration and exploitation objective. The technical ability to enhance natural fractures is available, the drilling depths are shallow, long term gas reserves are attractive, markets are available, drilling costs are reasonable, risks are very low, multiple drilling objectives are available, and the return on investment is good. Indiana Geological Survey records are well organized, accessible, and easy to use. The paper describes the New Albany shale play, play size, early exploration, geologic setting, completion techniques, and locating prime areas.

Minihan, E.D.; Buzzard, R.D. (Minihan/Buzzard Consulting Firm, Fort Worth, TX (United States))

1995-02-27T23:59:59.000Z

138

Devonian-Mississippian oil shale resources of Kentucky: a summary  

SciTech Connect (OSTI)

Assessment of the oil shale resources in Kentucky has continued with 75 NX cores available where the oil shale crops out or is overlain by relatively thin cover in the area from Estill County westward to Bullitt County. In this 14 county area, the total black shale section thins across the crest of the Cincinnati arch and changes stratigraphically from that characteristic of the Ohio Shale in Estill County to that of the New Albany Shale in Bullitt County. Despite this stratigraphic transition the two high-carbon zones (greater than 8.0% carbon) can be traced across the arch. As the traverse is followed from the east, the intervening low-carbon zones thin such that at the crest of the arch, there are areas where the entire section of black shale contains more than 8% carbon. Then upon leaving the crest the two high-carbon zones separate again with one remaining at the very top of the section and one in the lower part. In the 14 county area, there are approximately 3.8 x 10/sup 5/ acres of oil shale outcrop and approximately 7.8 x 10/sup 5/ acres underlain by oil shale at relatively shallow depths.

Barron, L.S.; Robl, T.L.; Kung, J.; Obley, J.

1985-02-01T23:59:59.000Z

139

Production data analysis type curves for the Devonian Shales  

E-Print Network [OSTI]

0. 12510 0. 12187 0. 12008 0. 11880 0. 11781 0. 11699 0, 11629 0. 11566 0. 11511 0. 11460 0. 11413 0. 11370 0. 11329 0. 11291 0. 11254 0. 11220 0. 11187 0. 11156 0. 11126 0. 11097 0. 10664 0. 10367 0. 10132 0. 99362E-01 0...

Hazlett, William Gregory

1985-01-01T23:59:59.000Z

140

Increased stray gas abundance in a subset of drinking water wells near Marcellus shale gas extraction  

E-Print Network [OSTI]

fingerprinting | fracking | hydrology and ecology Unconventional sources of gas and oil are transforming energy and horizontal drilling are also growing (4, 5). These concerns include changes in air quality (6), human health the greenhouse gas balance (8, 9). Perhaps the biggest health concern remains the potential for drinking water

Jackson, Robert B.

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


141

An Integrated Well Performance Study for Shale Reservoir Systems - Application to the Marcellus Shale  

E-Print Network [OSTI]

In this work we focus on the integration of two independent analyses, time-rate analysis and model-based production analysis, as an approach to resolve the uncertainty in estimating ultimate recovery (EUR) for wells in unconventional reservoirs...

Riser, Landon Jess

2013-11-15T23:59:59.000Z

142

Impact of the Marcellus Shale Gas Play on Current and Future CCS Activities  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr MayAtmospheric Optical Depth7-1D: Vegetation ProposedUsingFun withconfinementEtching. |EndecahemeEMSLImaging the0 Impact of the

143

Zero Discharge Water Management for Horizontal Shale Gas Well Development  

SciTech Connect (OSTI)

Hydraulic fracturing technology (fracking), coupled with horizontal drilling, has facilitated exploitation of huge natural gas (gas) reserves in the Devonian-age Marcellus Shale Formation (Marcellus) of the Appalachian Basin. The most-efficient technique for stimulating Marcellus gas production involves hydraulic fracturing (injection of a water-based fluid and sand mixture) along a horizontal well bore to create a series of hydraulic fractures in the Marcellus. The hydraulic fractures free the shale-trapped gas, allowing it to flow to the well bore where it is conveyed to pipelines for transport and distribution. The hydraulic fracturing process has two significant effects on the local environment. First, water withdrawals from local sources compete with the water requirements of ecosystems, domestic and recreational users, and/or agricultural and industrial uses. Second, when the injection phase is over, 10 to 30% of the injected water returns to the surface. This water consists of flowback, which occurs between the completion of fracturing and gas production, and produced water, which occurs during gas production. Collectively referred to as returned frac water (RFW), it is highly saline with varying amounts of organic contamination. It can be disposed of, either by injection into an approved underground injection well, or treated to remove contaminants so that the water meets the requirements of either surface release or recycle use. Depending on the characteristics of the RFW and the availability of satisfactory disposal alternatives, disposal can impose serious costs to the operator. In any case, large quantities of water must be transported to and from well locations, contributing to wear and tear on local roadways that were not designed to handle the heavy loads and increased traffic. The search for a way to mitigate the situation and improve the overall efficiency of shale gas production suggested a treatment method that would allow RFW to be used as make-up water for successive fracs. RFW, however, contains dissolved salts, suspended sediment and oils that may interfere with fracking fluids and/or clog fractures. This would lead to impaired well productivity. The major technical constraints to recycling RFW involves: identification of its composition, determination of industry standards for make-up water, and development of techniques to treat RFW to acceptable levels. If large scale RFW recycling becomes feasible, the industry will realize lower transportation and disposal costs, environmental conflicts, and risks of interruption in well development schedules.

Paul Ziemkiewicz; Jennifer Hause; Raymond Lovett; David Locke Harry Johnson; Doug Patchen

2012-03-31T23:59:59.000Z

144

MENTORING FROM THE TOP: STORIES OF SUCCESS & LESSONS LEARNED  

E-Print Network [OSTI]

The SUNY Registrar's Association building future leaders & other stories JudyTatum, Senior Director MohawkValley Community College, Utica branch The SUNY Registrar's Association Building future leadersValley Community College Located in Utica, NY- population 60,600 The first NYS Community College (1946) Utica

Nelson, Tim

145

Impact of Sorption Isotherms on the Simulation of CO2-Enhanced Gas Recovery and Storage Process in Marcellus Shale  

E-Print Network [OSTI]

and kerogen surfaces, very similar to the way methane is stored within coal beds. It has been demonstrated in gassy coals that on average; CO2 is preferentially adsorbed, displacing methane at a ratio of two for one or more. Black shale reservoirs may react similarly and desorb methane in the presence

Mohaghegh, Shahab

146

Economic viability of shale gas production in the Marcellus Shale; indicated by production rates, costs and current natural gas prices.  

E-Print Network [OSTI]

?? The U.S. natural gas industry has changed because of the recent ability to produce natural gas from unconventional shale deposits. One of the largest (more)

Duman, Ryan J.

2012-01-01T23:59:59.000Z

147

Techno-economic analysis of water management options for unconventional natural gas developments in the Marcellus Shale  

E-Print Network [OSTI]

The emergence of large-scale hydrocarbon production from shale reservoirs has revolutionized the oil and gas sector, and hydraulic fracturing has been the key enabler of this advancement. As a result, the need for water ...

Karapataki, Christina

2012-01-01T23:59:59.000Z

148

A new carcinosomatid eurypterid from the Siluro-Devonian of northern Vietnam  

E-Print Network [OSTI]

and distal podomeres of one appendage VI, entire opisthosoma and telson (Text-figs 3A, 4), although most of the postabdomen and telson are preserved on a separate piece (Text-figs 3D, 4). Coxa of appendage V 5-4 mm long. Podomere 2, 4-1 mm long. Podomere 3..., 4-4 mm long. Appendage VI entire. Coxa 24 mm long, 16 mm wide, convex posterior margin. Podomere 2 oval, 5-1 mm long, 9-7 mm wide. Podomere 3 narrow, 1-3 mm long, 9-3 mm wide. Podomere 4 narrow, wedge-shaped, anterior length 3-5 mm, width 8-5mm...

Selden, Paul A.; Truong, Doan Nhat

2002-01-01T23:59:59.000Z

149

Diagenesis of the Upper Devonian sandstones in Westmoreland County, southwestern Pennsylvania  

E-Print Network [OSTI]

and proximal turbidites were created as a result of different topography at the time of deposition. McCandless (1981) studied the subsurface Bradford sandstones in Indiana, Clearfieid, and Jefferson Counties adjacent to the study area. These sandstones were... are a function of mineralogy, temperature, fluid composition and amount of reactive surface area (Bruton, 1985). Mineral dissolution which releases cations into solution is attributed to a decrease in pH of the pore fluids. For the dissolution...

Zverina, Walter Charles

1989-01-01T23:59:59.000Z

150

The most pervasive systematic joints hosted by Devonian black shale of the Appa-  

E-Print Network [OSTI]

likely imparts a meaningful permeability anisot- ropy to these hydrocarbon source rocks. Keywords: joints driven exclusively by fluid pressure generated as a consequence of hydrocarbon-related maturation supple (Lawn, 1993). In a mechanically iso- tropic and homogeneous rock the stresses near the tip of a joint

Engelder, Terry

151

Petrology of the Devonian gas-bearing shale along Lake Erie helps explain gas shows  

SciTech Connect (OSTI)

Comprehensive petrologic study of 136 thin sections of the Ohio Shale along Lake Erie, when combined with detailed stratigraphic study, helps explain the occurrence of its gas shows, most of which occur in the silty, greenish-gray, organic poor Chagrin Shale and Three Lick Bed. Both have thicker siltstone laminae and more siltstone beds than other members of the Ohio Shale and both units also contain more clayshales. The source of the gas in the Chagrin Shale and Three Lick Bed of the Ohio Shale is believed to be the bituminous-rich shales of the middle and lower parts of the underlying Huron Member of the Ohio Shale. Eleven petrographic types were recognized and extended descriptions are provided of the major ones - claystones, clayshales, mudshales, and bituminous shales plus laminated and unlaminated siltstones and very minor marlstones and sandstones. In addition three major types of lamination were identified and studied. Thirty-two shale samples were analyzed for organic carbon, whole rock hydrogen and whole rock nitrogen with a Perkin-Elmer 240 Elemental Analyzer and provided the data base for source rock evaluation of the Ohio Shale.

Broadhead, R.F.; Potter, P.E.

1980-11-01T23:59:59.000Z

152

Biomarker and Paleontological Investigations of the Late Devonian Extinctions, Woodford Shale, Southern Oklahoma  

E-Print Network [OSTI]

the abundances of the algal cyst Tasmanites are elevated, while the fossils recovered from the upper Woodford Shale by this study and previous authors show an increase in diversity of brown-algae-type microfossils and low diversity benthic faunas dominated...

Nowaczewski, Vincent Stephen

2011-12-31T23:59:59.000Z

153

Gas potential of new Albany shale (Devonian-Mississippian) in the Illinois Basin  

SciTech Connect (OSTI)

A study to update and evaluate publicly available data relating to present and potential gas production from New Albany Shale in the Illinois basin was conducted cooperatively by the Indiana. Illinois, and Kentucky geological surveys (Illinois Basin Consortium), and was partially funded by the Gas Research Institute. Deliverables included a plate of stratigraphic cross sections and six basin-wide maps at a scale of 1:1,000,000. The New Albany Shale is an organic-rich brownish black shale present throughout the Illinois basin. Gas potential of the New Albany Shale may be great because it contains an estimated 86 tcf of natural gas and has produced modest volumes since 1858 from more than 60 fields, mostly in the southeastern part of the basin. Reservoir beds include organic-rich shales of the Grassy Creek (Shale), Clegg Creek, and Blocher (Shale) members. Limited geologic and carbon isotope data indicate that the gas is indigenous and thermogenic. T[sub max] data suggest that the gas generation begins at R[sub o] values of 0.53% and may begin at R[sub 0] values as low as 0.41% in some beds. New Albany Shale reservoirs contain both free gas in open-pore space and gas adsorbed on clay and kerogen surfaces. Natural fracturing is essential for effective reservoir permeability. Fractures are most common near structures such as faults, flexures, and buried carbonate banks. Based on limited data, fractures and joints have preferred orientations of 45-225[degrees] and 135-315[degrees]. Commercial production requires well stimulation to connect the well bore with the natural fracture system and to prop open pressure-sensitive near-borehole fractures. Current stimulations employ hydraulic fracture treatments using nitrogen and foam, with sand as a propping agent.

Comer, J.B.; Hasenmueller, N.R. (Indiana Geological Survey, Bloomington, IN (United States)); Frankie, W.T. (Illinois State Geological Survey, Champaign, IL (United States)); Hamilton-Smith, T. (Kentucky Geological Survey, Lexington, KY (United States))

1993-08-01T23:59:59.000Z

154

Evaluation of Devonian shale potential in Illinois, Indiana, and western Kentucky  

SciTech Connect (OSTI)

Potential natural gas resources in the New Albany Shale of the Illinois basin may be related to five key factors: relative organic content of the shale; relative thickness of the organically-rich shale; thermal maturity as related to depth of burial; presence of natural fractures; and type of organic matter. The shale that is organically richest is in southeastern Illinois and in most of the Indiana and Kentucky portions of the Illinois basin. The shales are thickest (about 400 feet) near the center of the basin in southeastern Illinois, southwestern Indiana, and adjacent parts of Kentucky. The area is deeply buried by younger rocks, and the organic matter has the highest thermal maturity. In addition, natural fault-induced fractures in the shale, which may aid in collecting gas from a larger volume of shale, may be present, since major faults along the Rough Creek Lineament and Wabash Valley Fault System cross the deeper part of the basin. Thus, this area near the basin center where the shale is thickest and rich organically and where fault-induced fractures may be present has the greatest potential for natural-gas resources. The eastern side of the basin, where the shale is organic-rich but thin, may have poor to moderate potential for additional discoveries of small gas fields similar to those found in the past. In western Illinois and the northern part of the basin, the potential is poor, because the organic content of the dominantly greenish-gray shale in this area is low. More exploration will be required to properly evaluate potential resources of natural gas that may exist in the New Albany Shale.

Not Available

1981-01-01T23:59:59.000Z

155

ELSEVIER Sedimentary Geology 124 (1999) 131147 UPb ages and geochemistry of granite pebbles from the Devonian  

E-Print Network [OSTI]

ELSEVIER Sedimentary Geology 124 (1999) 131­147 U­Pb ages and geochemistry of granite pebbles from 1998 Abstract The geochemical composition of some garnet-bearing biotite granite pebbles within from two samples. The granites have suffered low-grade metamorphism as shown by the development

Dörr, Wolfgang

156

SciTech Connect: Paleoecology of the Devonian-Mississippian black...  

Office of Scientific and Technical Information (OSTI)

shales contain abundant evidence of life from upper parts of the water column such as fish fossils, conodonts, algae and other phytoplankton; however, there is a lack of evidence...

157

Effects of reservoir geometry and permeability anisotropy on ultimate gas recovery in Devonian Shale reservoirs  

E-Print Network [OSTI]

for assistance and guidance during the course of my thesis research: L Dr. WL Lee for his wisdom, understanding, and technical expertise and for his insistence on striving for excellence as well as accuracy; 2. David Lancaster for his direction and his ability... Econotnic Projections for Selected Stimulated Cases, Fracture Parallel to k ?, L, =100 ft, 160-acre Well Spacing, 50-year Well Life . . 156 Economic Projections for Selected Stimulated Cases, Fracture Perpendicular to k ?, L, =100 ft, 160-acre Well...

Starnes, Lee McKennon

2012-06-07T23:59:59.000Z

158

Late devonian carbon isotope stratigraphy and sea level fluctuations, Canning Basin, Western Australia  

E-Print Network [OSTI]

reef, Canning Basin, Western Australia. Palaeontology 43,the Canning Basin, Western Australia. In: Loucks, R.G. ,Canning Basin, Western Australia. Ph.D Thesis, University of

Stephens, N P; Sumner, Dawn Y.

2003-01-01T23:59:59.000Z

159

THE NATURE OF EVOLUTIONARY RADIATIONS WITH A SPECIAL FOCUS ON DEVONIAN CALMONIID TRILOBITES  

E-Print Network [OSTI]

Trilobites were a diverse group of arthropods that left an extensive fossil record which are today used today to study macroevolutionary patterns and processes. A new species and form of olenelloidea trilobites (Nevadella ...

Abe, Francine Reiko

2010-07-22T23:59:59.000Z

160

Reservoir Characterization of Upper Devonian Gordon Sandstone, Jacksonburg, Stringtown Oil Field, Northwestern West Virginia  

SciTech Connect (OSTI)

This report gives results of efforts to determine electrofacies from logs; measure permeability in outcrop to study very fine-scale trends; find the correlation between permeability measured by the minipermeameter and in core plugs, define porosity-permeability flow units; and run the BOAST III reservoir simulator using the flow units defined for the Gordon reservoir.

Ameri, S.; Aminian, K.; Avary, K.L.; Bilgesu, H.I.; Hohn, M.E.; McDowell, R.R.; Patchen, D.L.

2002-05-21T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


161

Reservoir Characterization of Upper Devonian Gordon Sandstone, Jacksonburg, Stringtown Oil Field, Northwestern West Virginia  

SciTech Connect (OSTI)

This report gives results on use of a minipermeameter on cores to study very finescale trends in permeability, and use of neural networks to predict permeability in logged, uncored wells.

Ameri, S.; Aminian, K.; Avary, K.L.; Bilgesu, H.I.; Hohn, M.E.; McDowell, R.R.; Patchen, D.L.

2002-05-21T23:59:59.000Z

162

Reservoir characteristics of the Devonian Jauf Formation in Shedgum area, Saudi Arabia  

E-Print Network [OSTI]

. Detrital grains were classified as quartz (monocrystalline), feldspar, rock fragments (mostly polycrystalline quartz), others (includes heavy minerals, opaques, and mica), and matrix. Detrital grain compositions were then normalized to one hundred... percent. Cements were considered as the percent of the bulk composition. Mean grain size was determined from long axis measurements of 100 monocrystalline quartz grains in each thin section. The maximum grain size, and standard deviation were used...

Al-Duaiji, Abdulaziz Abdullah

1991-01-01T23:59:59.000Z

163

Depositional environment of Upper Devonian gas producing sandstones, Westmoreland County, southwestern Pennsylvania  

E-Print Network [OSTI]

for each sandstone; for each thin section, 100 monocrystalline quartz grains were counted. 37 LLOYDSVILLE SPORTSMAN ASSOCIATION I GRAIN SIZE mm 2. 0 I. O 0. 5 0. 25 O. I2 COMPOSITION /o CEM % 0 50 100 0 30 I 3I95 C Ep I I I I 3I97 FIRS T BRA... or polycrystalline as determined by the number of crystals within the quartz grain. Monocrystalline quartz is composed of a single crystal, and has simple or wavy extinction. Polycrystalline quartz contains more than one crystal within the grain. If crystals...

Work, Rebecca Miller

1988-01-01T23:59:59.000Z

164

Depositional environment of Upper Devonian sandstones in Westmoreland County, southwestern Pennsylvania  

E-Print Network [OSTI]

standard microscopic techniques. Composition was determined for each thin section by using 100 point counts. Mean size was determined from long axis measurement of 100 monocrystalline quartz grains in each thin section. The rock properties as determined... quartz to monocrystalline quartz to increase with increasing grain size. This relationship is demonstrated by a sample from the Bayard Sandstone (2544. 6) in which the amount of polycrystalline quartz is 41% of the total quartz and the mean grain...

McGee, Patricia Ann

1985-01-01T23:59:59.000Z

165

--No Title--  

U.S. Energy Information Administration (EIA) Indexed Site

benchmark Oct 15, 2014 Ohio's Utica Region now included in EIA's monthly Drilling Productivity Report Aug 12, 2014 See all state articles Household Energy Use Arizona...

166

Geologic and geochemical studies of the New Albany Shale Group (Devonian-Mississippian) in Illinois. Final report  

SciTech Connect (OSTI)

The Illinois State Geological Survey is conducting geological and geochemical investigations to evaluate the potential of New Albany Group shales as a source of hydrocarbons, particularly natural gas. Geological studies include stratigraphy and structure, mineralogic and petrographic characterization; analyses of physical properties; and development of a computer-based resources evaluation system. Geochemical studies include organic carbon content and trace elements; hydrocarbon content and composition; and adsorption/desorption studies of gas through shales. Separate abstracts have been prepared for each task reported.

Bergstrom, R.E.; Shimp, N.F.

1980-06-30T23:59:59.000Z

167

ICHNOTAXONOMY AND PALEOENVIRONMENTAL ANALYSIS OF TRACE FOSSILS IN THE LATE DEVONIAN CATSKILL FORMATION, NORTH-CENTRAL PENNSYLVANIA, USA  

E-Print Network [OSTI]

traces represent terraphilic to hydrophilic soil biota. Traces in strata with no evidence of pedogenesis represent aquatic organism behavior. Backfilled burrows--Beaconites antarcticus and B. barretti--represent dwelling and feeding by soil...

Jones, Wade Tyler

2011-12-31T23:59:59.000Z

168

Sulfide, phosphate, and minor element enrichment in the New Albany Shale (Devonian-Mississippian) of southern Indiana  

SciTech Connect (OSTI)

The upper part of the New Albany Shale is divided into three members, which in ascending order are: (1) the Morgan Trail Member, a laminated brownish-black shale; (2) the Camp Run Member, an interbedded brownish-black and greenish-gray shale; and (3) the Clegg Creek Member, also a laminated brownish-black shale. The Morgan Trail and Camp Run Members contain 5 to 6% total organic carbon (TOC) and 2% sulfide sulfur. Isotopic composition of sulfide in these members ranges from -5.0 to -20.0%. C/S plots indicate linear relationships between abundances of these elements characteristic of sediments deposited in a noneuxinic marine environment. The Clegg Creek Member contains 10 to 15% TOC and 2 to 6% sulfide sulfur. Isotopic composition of sulfide ranges from -5.0 to -40.0%. The most negative values are characteristic of syngenetic pyrite formed within an anoxic water column. Abundances of carbon and sulfur are higher and uncorrelated in this member, consistent with deposition in an euxinic environment. Further, DOP (degree of pyritization) values suggest that pyrite formation was generally iron limited throughout Clegg Creek deposition, but sulfur isotopes indicate that syngenetic (water column) pyrite becomes an important component in the sediment only in the upper part of the member. At the top of the Clegg Creek Member a zone of phosphate nodules and trace metal enrichment coincides with maximal TOC values. During euxinic deposition, phosphate and trace metals accumulated below the chemocline due to limited vertical circulation in the water column. Phosphate and trace metals released for organic matter during early diagenesis resulted in precipitation of metal-rich phosphate nodules.

Beier, J.A.

1988-01-01T23:59:59.000Z

169

REGIONAL DEPOSITIONAL TRENDS IN THE DEVONIAN GENESEO/BURKET BLACK SHALE BASED ON GAMMA RAY-DENSITY TRENDS.  

E-Print Network [OSTI]

??ABSTRACTGas shales are becoming increasingly important as new technologies are applied to enhance their production of natural gas. The Barnett, the Fayetteville, and the Haynesville (more)

Arnold, LaMichelle

2010-01-01T23:59:59.000Z

170

U.S. Geological Survey Open-File Report 2005-1268U.S. Geological Survey Open-File Report 2005-1268 Published 2005Published 2005  

E-Print Network [OSTI]

within reservoirs (Water, oil, gas cap)oil, gas cap) #12;The Devonian Shale - Middle andThe Devonian, 1975)(de Witt and others, 1975) A'A #12;Oil in Devonian Shale and OriskanyOil in Devonian Shale Natural Gas Resources in Devonian Black Shales,Assessment of Undiscovered Natural Gas Resources

Boyer, Elizabeth W.

171

NETL F 451.1/1-1, Categorical Exclusion Designation Form  

Broader source: Energy.gov (indexed) [DOE]

Bradford,Sullivan&Susquehanna Co,PA Zonal Isolation Improvement for Horizontal Wells Drilling in the Marcellus Shale Collection of real time data during cement jobs through...

172

NETL F 451.1/1-1, Categorical Exclusion Designation Form  

Broader source: Energy.gov (indexed) [DOE]

24 months Gary Covatch Houston, TX Zonal Isolation Improvement for Horizontal Wells Drilling in the Marcellus Shale Perform analytical assessments of lab test results and field...

173

CX-007941: Categorical Exclusion Determination | Department of...  

Broader source: Energy.gov (indexed) [DOE]

Categorical Exclusion Determination Zonal Isolation Improvement for Horizontal Wells Drilling in the Marcellus Shale CX(s) Applied: A9 Date: 02152012 Location(s): Texas...

174

CX-007940: Categorical Exclusion Determination | Department of...  

Broader source: Energy.gov (indexed) [DOE]

Categorical Exclusion Determination Zonal Isolation Improvement for Horizontal Wells Drilling in the Marcellus Shale CX(s) Applied: B3.6 Date: 02152012 Location(s): Texas...

175

NETL F 451.1/1-1, Categorical Exclusion Designation Form  

Broader source: Energy.gov (indexed) [DOE]

24 months Gary Covatch Houston, TX Zonal Isolation Improvement for Horizontal Wells Drilling in the Marcellus Shale Optimize zonal isolation through assessment of current...

176

NETL F 451.1/1-1, Categorical Exclusion Designation Form  

Broader source: Energy.gov (indexed) [DOE]

Co,PA Zonal Isolation Improvements for Horizontal Wells Drilled in the Marcellus Shale Activities performed will include: observing cementing operations including rig up,...

177

NETL F 451.1/1-1, Categorical Exclusion Designation Form  

Broader source: Energy.gov (indexed) [DOE]

Houston, TX Zonal Isolation Improvements for Horizontal Wells Drilled in the Marcellus Shale Perform analytical assessments of lab test results and field test results. Gary L....

178

NETL F 451.1/1-1, Categorical Exclusion Designation Form  

Broader source: Energy.gov (indexed) [DOE]

Co,PA Zonal Isolation Improvements for Horizontal Wells Drilled in the Marcellus Shale Observation of cementing operations and collecting small samples (25 lbs or less) of...

179

Lowering Drilling Cost, Improving Operational Safety, and Reducing  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Impact through Zonal Isolation Improvements for Horizontal Wells Drilled in the Marcellus Shale 10122.19.Final 11132014 Jeff Watters, Principal Investigator General Manager CSI...

180

(Data in kilograms of germanium content unless otherwise noted) Domestic Production and Use: The value of domestic refinery production of germanium, based upon an estimated  

E-Print Network [OSTI]

and Use: The value of domestic refinery production of germanium, based upon an estimated 2004 producer refinery in Utica, NY, produced germanium tetrachloride for optical fiber production. Another refinery

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


181

E-Print Network 3.0 - akinbo shale eastern Sample Search Results  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

...29 Eastern Devonian-Mississippian Oil Shale... ... Source: Laughlin, Robert B. - Department of Physics, Stanford University...

182

18 August 2009 www.fwbog.com Range Resources'(RRC) fourth  

E-Print Network [OSTI]

the Marcellus gas shale's breakout year. At the time, the "official" sources, including the U.S. Geological recoverable gas from Appalachian Basin black shales had mysteriously dropped out of sight.At a Petroleum authority on the recent Marcellus gas shale play, holds degrees from Penn State B.S. ('68), Yale M.S. ('72

Engelder, Terry

183

Water's Journey Through the Shale Gas Drilling and  

E-Print Network [OSTI]

Water's Journey Through the Shale Gas Drilling and Production Processes in the Mid-Atlantic Region: Marcellus shale drilling in progress, Beaver Run Reservoir, Westmoreland County. Credit: Robert Donnan. Gas. This publication fo- cuses mostly on Pennsylvania because it has the most Marcellus drilling activity of any state

Lee, Dongwon

184

A Political Ecology of Hydraulic Fracturing for Natural Gas in  

E-Print Network [OSTI]

environments, both in terms of perception and in terms of physical space. (Robbins 2004) #12;Outline ! Background of Marcellus Shale Gas Play ! Current Events: The Case of PA ! Geography of Fracking in Study Corbett #12;PA's Marcellus Shale Country is constructed as a Neoliberal Environment · Residents

Scott, Christopher

185

Conrad (Dan) Volz, DrPH, MPH Department of Environmental and Occupational Health,  

E-Print Network [OSTI]

of Pittsburgh, Graduate School of Public Health, cdv5@pitt.edu Director- Center for Healthy Environments://fractracker.org http://data.fractracker.org Marcellus Shale Gas Extraction; Public Health Impacts and Visualizations Associated with Intense Marcellus Shale Gas Production 1. Community and behavioral health impacts. 2

Sibille, Etienne

186

U.S. Department of the Interior U.S. Geological Survey  

E-Print Network [OSTI]

of natural gas. New devel- opments in drilling technology, along with higher wellhead prices, have made the Marcellus Shale an important natural gas resource. The Marcellus Shale extends from southern New York across- mercial quantities of gas from this shale requires large volumes of water to drill and hydraulically

Boyer, Elizabeth W.

187

Shale and the Environment Critical Need for a Government-University-  

E-Print Network [OSTI]

water and produces wastewater 1. Protecting surface waters from spills of chemicals or wastewater. 2 and Public Policy Center for Atmospheric Particle Studies #12;Drill Rigs Frac pumps Completion http://www.marcellus-shale.us Completion http://www.marcellus-shale.us Compressor stations Flaring Drilling Condensate Tanks Fracing

McGaughey, Alan

188

Underground Injection Wells as an Option for Disposal of Shale Gas Wastewaters: Policies & Practicality.  

E-Print Network [OSTI]

environments and are very salty, like the Marcellus shale and other oil and gas formations underlying the areaUnderground Injection Wells as an Option for Disposal of Shale Gas Wastewaters: Policies), Region 3. Marcellus Shale Educational Webinar, February 18, 2010 (Answers provide below by Karen Johnson

Boyer, Elizabeth W.

189

1Prepared by BG Rahm & SJ Riha (NYS Water Resources Institute), D Yoxtheimer (Penn State Marcellus Center for Outreach and Research), E Boyer (PA Water Resources Research Center), D Carder (WVU Center for Alternative Fuels, Engines, and Emissions), K Davi  

E-Print Network [OSTI]

for Alternative Fuels, Engines, and Emissions), K Davis & S Belmecheri (Penn State University) Environmental water Center for Outreach and Research), E Boyer (PA Water Resources Research Center), D Carder (WVU Center sessions: 1. What data sources are currently available for collecting information on water and air systems

190

Natural gas distributed throughout the Marcellus black shale in northern Appalachia could boost proven U.S. gas reserves by trillions of cubic feet (see http://live.psu.edu/story/28116).  

E-Print Network [OSTI]

Pennsylvania Public Broadcasting television program (see http:/wpsu.org/gasrush) explored issues landowners royalties, which are agreed upon shares of the value of gas lifted from natural deposits

Boyer, Elizabeth W.

191

Stratigraphic and structural configuration of the Navajo (Jurassic) through Ouray (Mississippian-Devonian) formations in the vicinity of Davis and Lavender Canyons, southeastern Utah  

SciTech Connect (OSTI)

This study developed a three-dimensional computer model of stratigraphic and structural relationships within a 3497-km/sup 2/ (1350-mi/sup 2/) study area centered on the proposed site for a high-level nuclear waste repository in southeastern Utah. The model consists of a sequence of internally reconciled isopach and structure contour maps horizontally registered and stored in stratigraphic order. This model can be used to display cross sections, perspective block diagrams, or fence diagrams at any orientation; estimate depth of formation contacts and thicknesses for any new stratigraphic or hydrologic boreholes; facilitate ground-water modeling studies; and evaluate the structural and stratigraphic evolution of the study area. This study also includes limited evaluations of aquifer continuity in the Elephant Canyon and Honaker Trail Formations, and of salt dissolution and flowage features as interpreted from geophysical logs. The study identified a long history of movement in the fault system in the north-central part of the study area and a major salt flowage feature in the northeastern part. It describes the Elephant Canyon Formation aquifer as laterally limited, the Honaker Trail Formation aquifer as fairly continuous over the area, and Beef Basin in the southern part of the area as a probable dissolution feature. It also concludes that the Shay-Bridger Jack-Salt Creek Graben system is apparently a vertically continuous feature between the basement and ground surface. No stratigraphic or structural discontinuities were detected in the vicinity of Davis Canyon that appear to be detrimental to the siting of a waste repository.

McCleary, J.R.; Romie, J.E.

1986-04-01T23:59:59.000Z

192

Recovery of bypassed oil in the Dundee Formation (Devonian) of the Michigan Basin using horizontal drains. Final report, April 28, 1994--December 31, 1997  

SciTech Connect (OSTI)

Total hydrocarbon production in the Michigan Basin has surpassed 1 billion barrels (Bbbls) and total unrecovered reserves are estimated at 1--2 BBbls. However, hydrocarbon production in Michigan has fallen from 35 MMbbls/yr in 1979 to about 10 MMbbls/yr in 1996. In an effort to slow this decline, a field demonstration project designed around using a horizontal well to recover bypassed oil was designed and carried out at Crystal Field in Montcalm County, MI. The project had two goals: to test the viability of using horizontal wells to recover bypassed oil from the Dundee Formation, and to characterize additional Dundee reservoirs (29) that are look alikes to the Crystal Field. As much as 85 percent of the oil known to exist in the Dundee Formation in the Michigan Basin remains in the ground as bypassed oil. Early production techniques in the 137 fields were poor, and the Dundee was at risk of being abandoned, leaving millions of barrels of oil behind. Crystal Field in Montcalm County, Michigan is a good example of a worn out field. Crystal Field was once a prolific producer which had been reduced to a handful of wells, the best of which produced only 5 barrels per day. The demonstration well drilled as a result of this project, however, has brought new life to the Crystal Field. Horizontal drilling is one of the most promising technologies available for oil production. The new well was completed successfully in October of 1995 and has been producing 100 barrels of oil per day, 20 times better than the best conventional well in the field.

Wood, J.R.; Pennington, W.D.

1998-09-01T23:59:59.000Z

193

Depositional and dissolutional processes and their resulting thinning patterns within the Middle Devonian Prairie Formation, Williston basin, North Dakota and Montana  

SciTech Connect (OSTI)

Within the Williston basin, thickness variations of the Prairie Formation are common and are interpreted to originate by two processes: differential accumulation of salt during deposition and differential removal of salt by dissolution. Unambiguous evidence for each process is rare because the Prairie/Winnipegosis interval is seldom cored within the US portion of the basin. Therefore, indirect methods, using well logs, provide the principal method for identifying characteristics of the two processes. The results of this study indicate that the two processes can be distinguished using correlations within the Prairie Formation. Several regionally correlative brining-upward and probably shoaling-upward sequences occur within the Prairie Formation. Near the basin center, the lowermost sequence is transitional with the underlying Winnipegosis Formation. This transition is characterized by thinly laminated basal carbonates that become increasingly interbedded with anhydrites of the basin-centered Ratner member. The remainder of the sequence progresses up through halite and culminates in the halite-dominated Esterhazy potash beds. Two overlying sequences also brine upward; however, these sequences lack the basal anhydrite and instead begin with halite and culminate in the Belle Plaine and Mountrail potash members, respectively. A fourth sequence is indicated by several feet of halite capping the Mountrail member in some parts of the basin. Subsequent erosion or dissolution prior to burial may have removed the upper portion of this sequence. Cross sections show that the lower Prairie gradually decreases in thickness from the basin to its margins. This thickens variation is most simply explained by decreasing accommodation potential due to decreased basin topography away from the basin depocenter and by depositional onlap of the Prairie toward the basin margins.

Oglesby, C.A.

1988-07-01T23:59:59.000Z

194

CX-008914: Categorical Exclusion Determination | Department of...  

Broader source: Energy.gov (indexed) [DOE]

Categorical Exclusion Determination Zonal Isolation Improvement for Horizontal Wells Drilling in the Marcellus Shale CX(s) Applied: A9, B3.6 Date: 08292012 Location(s):...

195

CX-008518: Categorical Exclusion Determination | Department of...  

Broader source: Energy.gov (indexed) [DOE]

Categorical Exclusion Determination Zonal Isolation Improvement for Horizontal Wells Drilling in the Marcellus Shale CX(s) Applied: A9, A11, B3.6 Date: 07122012 Location(s):...

196

CX-012130: Categorical Exclusion Determination  

Broader source: Energy.gov [DOE]

Zonal Isolation Improvements for Horizontal Wells Drilled in the Marcellus Shale CX(s) Applied: A9 Date: 05/27/2014 Location(s): Texas Offices(s): National Energy Technology Laboratory

197

CX-012142: Categorical Exclusion Determination  

Broader source: Energy.gov [DOE]

Zonal Isolation Improvements for Horizontal Wells Drilled in the Marcellus Shale CX(s) Applied: B3.11 Date: 05/27/2014 Location(s): Pennsylvania, Pennsylvania, Pennsylvania Offices(s): National Energy Technology Laboratory

198

Microsoft Word - EPAct_TRS_Greene Co Site_final_20140915.docx  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

A.; Wells, A.; Diehl, R; Blaushild, D.; Sams, J.; and Veloski, G An Evaluation of Fracture Growth and GasFluid Migration as Horizontal Marcellus Shale Gas Wells are...

199

Risk assessment of groundwater contamination from hydraulic fracturing fluid spills in Pennsylvania  

E-Print Network [OSTI]

Fast-paced growth in natural gas production in the Marcellus Shale has fueled intense debate over the risk of groundwater contamination from hydraulic fracturing and the shale gas extraction process at large. While several ...

Fletcher, Sarah Marie

2012-01-01T23:59:59.000Z

200

E-Print Network 3.0 - avg process Sample Search Results  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Laboratories Collection: Mathematics ; Computer Technologies and Information Sciences 79 Hydrothermal venting and basin evolution (Devonian, South China): Constraints from rare...

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


201

Risk Assessment and Monitoring of Stored CO2 in Organic Rocks Under Non-Equilibrium Conditions  

SciTech Connect (OSTI)

The USA is embarking upon tackling the serious environmental challenges posed to the world by greenhouse gases, especially carbon dioxide (CO2). The dimension of the problem is daunting. In fact, according to the Energy Information Agency, nearly 6 billion metric tons of CO2 were produced in the USA in 2007 with coal-burning power plants contributing about 2 billion metric tons. To mitigate the concerns associated with CO2 emission, geological sequestration holds promise. Among the potential geological storage sites, unmineable coal seams and shale formations in particular show promise because of the probability of methane recovery while sequestering the CO2. However. the success of large-scale sequestration of CO2 in coal and shale would hinge on a thorough understanding of CO2's interactions with host reservoirs. An important parameter for successful storage of CO2 reservoirs would be whether the pressurized CO2 would remain invariant in coal and shale formations under reasonable internal and/or external perturbations. Recent research has brought to the fore the potential of induced seismicity, which may result in caprock compromise. Therefore, to evaluate the potential risks involved in sequestering CO2 in Illinois bituminous coal seams and shale, we studied: (i) the mechanical behavior of Murphysboro (Illinois) and Houchin Creek (Illinois) coals, (ii) thermodynamic behavior of Illinois bituminous coal at - 100oC ? T ? 300oC, (iii) how high pressure CO2 (up to 20.7 MPa) modifies the viscosity of the host, (iv) the rate of emission of CO2 from Illinois bituminous coal and shale cores if the cores, which were pressurized with high pressure (? 20.7 MPa) CO2, were exposed to an atmospheric pressure, simulating the development of leakage pathways, (v) whether there are any fractions of CO2 stored in these hosts which are resistance to emission by simply exposing the cores to atmospheric pressure, and (vi) how compressive shockwaves applied to the coal and shale cores, which were pressurized with high pressure CO2, determine the fate of sequestered CO2 in these cores. Our results suggested that Illinois bituminous coal in its unperturbed state, i.e., when not pressurized with CO2, showed large variations in the mechanical properties. Modulus varied from 0.7 GPa to 3.4 GPa even though samples were extracted from a single large chunk of coal. We did not observe any glass transition for Illinois bituminous coal at - 100oC ? T ? 300oC, however, when the coal was pressurized with CO2 at ambient ? P ? 20.7 MPa, the viscosity of the coal decreased and inversely scaled with the CO2 pressure. The decrease in viscosity as a function of pressure could pose CO2 injection problems for coal as lower viscosity would allow the solid coal to flow to plug the fractures, fissures, and cleats. Our experiments also showed a very small fraction of CO2 was absorbed in coal; and when CO2 pressurized coals were exposed to atmospheric conditions, the loss of CO2 from coals was massive. Half of the sequestered gas from the coal cores was lost in less than 20 minutes. Our shockwave experiments on Illinois bituminous coal, New Albany shale (Illinois), Devonian shale (Ohio), and Utica shale (Ohio) presented clear evidence that the significant emission of the sequestered CO2 from these formations cannot be discounted during seismic activity, especially if caprock is compromised. It is argued that additional shockwave studies, both compressive and transverse, would be required for successfully mapping the risks associated with sequestering high pressure CO2 in coal and shale formations.

Malhotra, Vivak

2014-06-30T23:59:59.000Z

202

(Data in kilograms of germanium content, unless otherwise noted) Domestic Production and Use: The value of domestic refinery production of germanium, based upon an estimated  

E-Print Network [OSTI]

and Use: The value of domestic refinery production of germanium, based upon an estimated 2003 producer. A germanium refinery in Utica, NY, produced germanium tetrachloride for optical fiber production. Another refinery in Oklahoma produced refined germanium compounds for the production of fiber optics, infrared

203

(Data in kilograms of germanium content, unless otherwise noted) Domestic Production and Use: The value of domestic refinery production of germanium, based upon the 2002  

E-Print Network [OSTI]

and Use: The value of domestic refinery production of germanium, based upon the 2002 producer price-bearing materials generated from the processing of zinc ores. The germanium refinery in Utica, NY, produced germanium tetrachloride for optical fiber production. The refinery in Oklahoma doubled its production

204

(Data in kilograms of germanium content unless otherwise noted) Domestic Production and Use: The value of domestic refinery production of germanium, based upon an estimated  

E-Print Network [OSTI]

and Use: The value of domestic refinery production of germanium, based upon an estimated 2008 producer of 2008. A germanium refinery in Utica, NY, produced germanium tetrachloride for optical fiber production. Another refinery in Oklahoma produced refined germanium compounds for the production of fiber optics

205

(Data in kilograms of germanium content unless otherwise noted) Domestic Production and Use: The value of domestic refinery production of germanium, based upon an estimated  

E-Print Network [OSTI]

and Use: The value of domestic refinery production of germanium, based upon an estimated 2007 producer in the fourth quarter of 2007. A germanium refinery in Utica, NY, produced germanium tetrachloride for optical fiber production. Another refinery in Oklahoma produced refined germanium compounds for the production

206

Author's personal copy Fossil brines preserved in the St-Lawrence Lowlands,  

E-Print Network [OSTI]

temperatures higher than 250 C, allowing for thermal maturation of local gas-prone source rocks (Utica shales degassing, are identical to their production ratios in rocks. The source of salinity (halite dissolution al., 2003). However, metamorphic and magmatic rocks are not a good source of halogens. Most scholars

Long, Bernard

207

172 Newark High School 83 Reynoldsburg High School  

E-Print Network [OSTI]

AU09 HS 172 Newark High School 83 Reynoldsburg High School 71 Heath High School 69 Granville High School 57 Licking Valley High School 54 Northridge High School 54 Watkins Memorial High Scho 51 Sheridan High School 50 Lincoln High School 49 Mount Vernon High School 46 Tri-valley High School 43 Utica High

Jones, Michelle

208

Lawrence Head Volcanics and Dunnage Melange, Newfoundland Appalachians: Ordovician ridge subduction or back arc rift? William S.F. Kidd1, Adam Schoonmaker2, Stephen E. DeLong1, John F. Bender3  

E-Print Network [OSTI]

of Atmospheric and Environmental Sciences, University at Albany, Albany NY 12222 2 Department of Geology, Utica Abstract We review the geological setting and report new geochemical trace element data from the Ordovician Exploits Group in the same stratigraphic position just below the mid-Ordovician cherts and black shales

Kidd, William S. F.

209

The Burke Library Archives, Columbia University Libraries, Union Theological Seminary, New York  

E-Print Network [OSTI]

to the State Anti-Slavery Convention in Utica, NY. He attended New Haven Theological Seminary from 1837-1839, and completed his Masters of Divinity degree at Union Theological Seminary in 1840. Bush served a number donated to the Burke Library exemplify the writing methods of ancient Asia. Palm leaf manuscripts date

Salzman, Daniel

210

Fault Tolerant Artificial Neural Networks Dhananjay. S. Phatak  

E-Print Network [OSTI]

and Applications Conference, May 1995, Utica/Rome, NY) ABSTRACT This paper investigates improved training proce to some extent. However, a brute force method of replica- tions proposed in [1, 2] seems to achieve is not enough; better learning algorithms and synthesis methods must be developed in order to achieve

Phatak, Dhananjay S.

211

Computer-assisted Mutagenesis of Ecotin to Engineer Its Secondary Binding Site for Urokinase Inhibition*  

E-Print Network [OSTI]

. Fletterick**, Irwin Kuntz**, and Charles S. Craik** From the Departamento de Cie^ncias Farmace^uticas the focused, and complete libraries were RRWS and R(R/N)QL, respectively. Inhibition constant deter- minations of combinatorial methods and computer algorithms designed to predict stronger binders has allowed us to obtain

Craik, Charles S.

212

Nutritional status of Amerindian children from the Beni River (lowland Bolivia) as related to environmental, maternal and  

E-Print Network [OSTI]

Nutritional status of Amerindian children from the Beni River (lowland Bolivia) as related pour le Developpement (IRD, France) de Bolivia, Av. Hernando Siles #5290, Esq Calle 7 Obrajes, PB 9214, La Paz, Bolivia: 2 Instituto SELADIS (Facultad de Ciencias Farmaceuticas y Bioqui

Paris-Sud XI, Universit de

213

Geologic and geochemical studies of the New Albany Group (Devonian Black Shale) in Illinois to evaluate its characteristics as a source of hydrocarbons. Quarterly progress report, January 1-March 31, 1980  

SciTech Connect (OSTI)

This project is a detailed analysis of the lithology, stratigraphy, and structure of the New Albany Group in Illinois to determine those characteristics of lithology, thickness, regional distribution, vertical and lateral variability, and deformation that are most relevant to the occurrence of hydrocarbons. The mineralogic and petrographic properties of the New Albany Shale in Illinois are characterized. This includes the quantitative and qualitative characterization, by optical and x-ray techniques, of the inorganic mineral constituents, the dispersed organic matter, and the fabric of the shale. Not less than 49 major, minor, and trace elements are determined in 300 to 500 shale samples, which are representative cross sections of the cores taken. Organic and mineral carbon are included; total hydrogen; total sulfur and when that exceeds 0.5%, pyritic and sulfate sulfur. Also, other elements observed during normal routine analysis are reported. The character of off-gases from approximately 10-foot intervals in cores collected in the Illinois Basin is determined. In addition, the relative distribution of hydrocarbons is determined in ten specially prepared core samples, which are the same as those in previous unit. The carbon isotopic composition of methane in off-gases is determined from core samples whenever sufficient methane can be collected. This data is compared to other pertinent data such as gas composition and vitrinite reflectance for the purpose of making interpretations as to the origin and maturity of the gas. Laboratory experiments are performed to study the relative effects and significance of chemical and isotopic fractionation that occurs as gas is released from core samples. Data accumulated can be evaluated to gain a better understanding of the origin, migration, and location of natural gas associated with the shales.

Bergstrom, R.E.; Shimp, N.F.

1980-04-01T23:59:59.000Z

214

abeta oligomers show: Topics by E-print Network  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Creek showing (Candy and Deep Purple claims) is hosted by Middle Devonian carbonate rocks in the southem Rocky Mountains oi British Columbia. The property lies near the...

215

apolipoprotein a-i showed: Topics by E-print Network  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Creek showing (Candy and Deep Purple claims) is hosted by Middle Devonian carbonate rocks in the southem Rocky Mountains oi British Columbia. The property lies near the...

216

anti-m2 scfv shows: Topics by E-print Network  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Creek showing (Candy and Deep Purple claims) is hosted by Middle Devonian carbonate rocks in the southem Rocky Mountains oi British Columbia. The property lies near the...

217

Subsurface horizontal microfracture propagation within the middle member of the Bakken Formation, Williston Basin, North Dakota.  

E-Print Network [OSTI]

??The Devonian-Mississippian Bakken Formation of the Williston basin does not outcrop. All rock samples are obtained by coring. Open, uncemented, horizontal mode I (joints, with (more)

Warner, Travis Blackburn.

2011-01-01T23:59:59.000Z

218

Sensitivity of seismic reflections to variations in anisotropy in the Bakken Formation, Williston Basin, North Dakota.  

E-Print Network [OSTI]

??The Upper DevonianLower Mississippian Bakken Formation in the Williston Basin is estimated to have significant amount of technically recoverable oil and gas. The objective of (more)

Ye, Fang, geophysicist.

2010-01-01T23:59:59.000Z

219

N E U R O C I N C I A 4 2 G A L I L E U | S E T E M B R O 2 0 0 7  

E-Print Network [OSTI]

EUA em relação ao programa nuclear de seu país e analisa acidentes aéreos no Brasil >> Não é incomum Meshkati é um especialista em segurança industrial nas áreas de energia nuclear, química e aeronáutica Chernobyl em solo iraniano. Meshkati também acredita que os grandes acidentes que aconteceram no Brasil nos

Valero-Cuevas, Francisco

220

2004 Geological Society of America. For permission to copy, contact Copyright Permissions, GSA, or editing@geosociety.org. Geology; April 2004; v. 32; no. 4; p. 305308; doi: 10.1130/G20202.1; 5 figures. 305  

E-Print Network [OSTI]

in Tennessee and Kentucky show extensive erosion surfaces within the Chattanooga and New Albany Shales that al. 305 Pyrite ooids in Devonian black shales record intermittent sea-level drop and shallow 2008, Oak Ridge, Tennessee 37831-6365, USA ABSTRACT Upper Devonian black shales of the eastern United

Polly, David

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


221

Agenda for 2014 Meeting of MSRL March 3-7, 2014  

E-Print Network [OSTI]

3:15 PM Pore evolution during thermal maturation: Eagle Ford formation: Tongwei Zhang 3:45 PM Pore: (Eagle Ford, Marcellus, Niobrara, Atoka, Wolfcamp, etc.) Main Meeting: Thursday. March 6 Friday March 7 Lu 9:30 AM Defining facies continuity and correlatability in the Eagle Ford Fm: Steve Ruppel 10:00 AM

Texas at Austin, University of

222

A1. SHALE GAS PRODUCTION GROWTH IN THE UNITED STATES..............................1 A2. VARIABILITY IN SHALE WELL PRODUCTION PERFORMANCE ............................1  

E-Print Network [OSTI]

basin, and of late the Eagle Ford shale located in southwest Texas. Figure A1 illustrates the growth reservoir pressure, total organic content, thermal maturity, porosity, the presence of natural fractures Eagle Ford Marcellus Haynesville Woodford Fayetteville Barnett Figure A1. Growth in natural gas

223

Reply to Davies: Hydraulic fracturing remains a possible mechanism for  

E-Print Network [OSTI]

LETTER Reply to Davies: Hydraulic fracturing remains a possible mechanism for observed methane in aquifers overlying the Marcellus formation but asserts that we prematurely ascribed its cause to hydraulic mechanisms were leaky gas well casings and the possibility that hydraulic fracturing might generate new

Jackson, Robert B.

224

A project funded by the Pennsylvania  

E-Print Network [OSTI]

of Community and the Economy (CSCE) at Lycoming College MARCELLUS NATURAL GAS DEVELOPMENT'S EFFECT ON HOUSING Shale natural gas industry, broadly defined, is having on housing, also broadly defined, across for the Study of Community and the Economy (CSCE) Lycoming College Williamsport, PA 17701 October 31, 2011 #12;i

Boyer, Elizabeth W.

225

Pennsylvania Water Resources Research Center, Penn State Institutes of Energy and the  

E-Print Network [OSTI]

"Characterization, treatment, and reuse of frac water related to horizontal hydraulic fracturing of Marcellus ShalePennsylvania Water Resources Research Center, Penn State Institutes of Energy and the Environment Annual Technical Report FY 2009 Pennsylvania Water Resources Research Center, Penn State Institutes

226

Top-Down Modeling; Practical, Fast-Track, Reservoir Modeling for Shale Formations AAPG/SEG/SPE/SPWLA Hedberg Conference, Austin, TX December 2010  

E-Print Network [OSTI]

for New Albany, Lower Huron and Marcellus Shales. Top-Down Modeling technology integrates reservoir1 Top-Down Modeling; Practical, Fast-Track, Reservoir Modeling for Shale Formations AAPG OF SHALE RESOURCE PLAYS" DECEMBER 5-10, 2010 ­ AUSTIN, TEXAS Top-Down Modeling; Practical, Fast Track

Mohaghegh, Shahab

227

CX-011418: Categorical Exclusion Determination  

Broader source: Energy.gov [DOE]

Zonal Isolation Improvements for Horizontal Wells Drilled in the Marcellus Shale CX(s) Applied: A9, A11, B3.6, B3.11 Date: 12/18/2013 Location(s): Pennsylvania, Pennsylvania, Pennsylvania Offices(s): National Energy Technology Laboratory

228

Hydraulic Fracturing and Horizontal Gas Well Drilling Reference List This list is in no way exhaustive. Rather, it attempts to provide a set of primary references that offer key pieces of  

E-Print Network [OSTI]

development Impact Assessment of Natural Gas Production in the New York City Water Supply Watershed (2009). NYCDEP http://home2.nyc.gov/html/dep/html/news/natural_gas_drilling.shtml Review of water related and infiltration events Short Scholarly Features Natural Gas Plays in the Marcellus Shale: Challenges & Potential

Wang, Z. Jane

229

The public relations department at Range Resources delivered two alternate draft press releases to the desk of John Pinkerton, Range's CEO: one expressing support for a new regulatory bill, and the other  

E-Print Network [OSTI]

up at the poster hanging on his office wall depicting the natural gas resources in the Marcellus. Background: Natural Gas Geology and Natural Gas Shale Formations A 2008 study undertaken by the Energy natural gas in the United States.1 This figure accounted for undiscovered, unproved, and unconventional

Edwards, Paul N.

230

College of AgriCulturAl SCienCeS AgriCulturAl reSeArCh And CooperAtive extenSion Shale: What  

E-Print Network [OSTI]

more economically feasible. Increasing demand for cleaner domestic energy will bring about continuing compensation for the use of the resource and as the gas industry develops the regional drilling infra and development of the Marcellus for citizens, local officials, and community members to constantly remember

Boyer, Elizabeth W.

231

Margaret A. Ormsby Oral History Project Compiled by Christopher Hives (1999)  

E-Print Network [OSTI]

Margaret A. Ormsby Oral History Project fonds Compiled by Christopher Hives (1999) University Alphabetically by Interviewee 1-6 #1 John Bovey (April 9, 1999) - 2 tapes 1-7 #2 Keith Ralston (May 4, 1999) 1 Marcellus (May 11, 1999) 1-10 #5 Lewis G. Thomas (May 12, 1999) 1-11 #6 Keith Ralston (May 12, 1999) 1-12 #7

Handy, Todd C.

232

Beyond Population and Environment: Household Demographic Life Cycles and Land Use Allocation  

E-Print Network [OSTI]

with different economic and ecological implications. We estimate a system of structural equations that accounts Small Farms in the Amazon Stephen G. Perz & Robert T. Walker & Marcellus M. Caldas Published online: 6 in human-environment interactions, demo- graphic environmental research needs to move beyond

Walker, Robert T.

233

Implementation of FracTracker.org: A GeoWeb platform to manage and communicate shale gas information  

E-Print Network [OSTI]

Implementation of FracTracker.org: A GeoWeb platform to manage and communicate shale gas Health, GSPH. Background Natural gas drilling in shale formations worldwide employs relatively new drilling in the Marcellus Shale (See Figure 1.) of the northeastern United States necessitates better

Sibille, Etienne

234

What is it? A process that  

E-Print Network [OSTI]

and oil from shale rock by pumping sand, water, and various toxic chemicals into the rock. Why blowout, Bradford Country, PA (Marcellus Shale) in April 2011 BP Oil spill, Gulf of Mexico in April 2010 is it important? It is an advanced drilling method that can utilize the vast reserves of shale deposits in the US

Toohey, Darin W.

235

Statement of David P. Russ Regional Executive for the Northeast, U.S. Geological Survey  

E-Print Network [OSTI]

of geologicallybased energy resources, including unconventional resources such as shale gas and shale oil. USGS a new assessment of undiscovered oil and gas resources of the Marcellus Shale. Results from Subcommittee To Examine Shale Gas Production and Water Resources in the Eastern United States October 20

Torgersen, Christian

236

Review Meeting Mudrock Systems Research Laboratory  

E-Print Network [OSTI]

Ford Formation, South Texas Basin: Wang Prospectivity and Producibility of Shale Oil Resource Systems system of the Marcellus Shale: Milliken 11:25 ­ 11:55 AM Variations in pore types and abundance in the Pearsall Shale: Ko 11:55 ­ 1:00 PM CATERED LUNCH 1:00 ­ 1:30 PM Microfractures in Organic-Rich Mudrocks

Texas at Austin, University of

237

Breakthrough Water Cleaning Technology Could Lessen Environmental Impacts from Shale Production  

Broader source: Energy.gov [DOE]

A novel water cleaning technology currently being tested in field demonstrations could help significantly reduce potential environmental impacts from producing natural gas from the Marcellus shale and other geologic formations, according to the Department of Energys National Energy Technology Laboratory

238

Kentucky, Tennessee: corniferous potential may be worth exploring  

SciTech Connect (OSTI)

The driller's term, corniferous, refers to all carbonate and clastic strata, regardless of geologic age, underlying the regional unconformity below the late Devonian-early Mississippian New Albany shale and overlying the middle Silurian Clinton shale in the study area. From oldest to youngest, the formations that constitute the corniferous are the middle Silurian Keefer formation, the middle Silurian Lockport dolomite, the upper Silurian Salina formation, the lower Devonian Helderberg limestone, the lower Devonian Oriskanysandstone, the lower Devonian Onondaga limestone, and in the extreme western portion of the study area, the middle Devonian Boyle dolomite. The overlying New Albany shale also is termed Ohio shale or Chattanooga shale in the Appalachian Basin. To drillers, it is known simply as the black shale. The study area is located in E. Kentucky on the western flank of the Appalachian Basin and covers all or parts of 32 counties.

Currie, M.T.

1982-05-01T23:59:59.000Z

239

Perithecial ascomycetes from the 400 million year old Rhynie chert: an example of ancestral polymorphism  

E-Print Network [OSTI]

We describe a perithecial, pleomorphic ascomycetous fungus from the Early Devonian (400 mya) Rhynie chert; the fungus occurs in the cortex just beneath the epidermis of aerial stems and rhizomes of the vascular plant ...

Taylor, Thomas N.; Hass, H.; Kerp, H.; Krings, Michael; Hanlin, R.T.

2005-01-01T23:59:59.000Z

240

ELSEVIER Tectonophysics247(1995)121-132 TECTONOPHYSICS  

E-Print Network [OSTI]

in Western New York. Taken together, these samples contain the complete Devonian section which in the study is facilitated by oriented core samples from 31 wells drilled as part of the US Department of Energy's Eastern

Engelder, Terry

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


241

Genesis of zoned granite plutons in the Iapetus Suture Zone: new constraints from high-precision micro-analysis of accessory minerals  

E-Print Network [OSTI]

The Trans-Suture Suite (TSS) of granitic plutons located in Northern Britain span the Iapetus Suture and represent a particularly enigmatic stage of post-Caledonian Devonian magmatism. Despite calc-alkaline affinities, ...

Miles, Andrew James

2013-07-01T23:59:59.000Z

242

J. Paleont., 83(1), 2009, pp. 7079 Copyright 2009, The Paleontological Society  

E-Print Network [OSTI]

Foerstia White, 1923, are the remains of an enigmatic Late Devonian plant-like organism of possible terres organic remains are known from numerous localities in the eastern United States, largely from offshore

Schieber, Juergen

243

APPENDIX C * Seniority Units  

E-Print Network [OSTI]

, Bookstores, Residences, Food Services) Agricultural, Life and Environmental Sciences, Faculty of Office of the Dean Agriculture, Food and Nutritional Sciences Devonian Botanic Garden Human Ecology Renewable Asian Studies Economics English and Film Studies History and Classics Arts Resource Centre Linguistics

MacMillan, Andrew

244

Chemostratigraphy And Geochemical Constraints On The Deposition Of The Bakken Formation, Williston Basin, Eastern Montana And Western North Dakota.  

E-Print Network [OSTI]

??Rowe, Harold The late Devonian-early Mississippian Bakken Formation was deposited in a structural-sedimentary intracratonic basin that extends across a large part of modern day North (more)

Maldonado, David Nyrup

2013-01-01T23:59:59.000Z

245

Chemostratigraphy And Geochemical Constraints On The Deposition Of The Bakken Formation, Williston Basin, Eastern Montana And Western North Dakota.  

E-Print Network [OSTI]

??Rowe, Harold The late Devonian-early Mississippian Bakken Formation was deposited in a structural-sedimentary intracratonic basin that extends across a large part of modern day North (more)

Maldonado, David Nyrup

2014-01-01T23:59:59.000Z

246

Property measurement and correlation for homogeneous and naturally fractured low permeability cores  

E-Print Network [OSTI]

This thesis presents the results of measurements from ten naturally fractured Devonian Shale cores using a new laboratory technique to determine the distinctive properties of the matrix and the fractures. The new technique is based on a pressure...

Fan, Jin

2012-06-07T23:59:59.000Z

247

Deformation of shale: mechanical properties and indicators of mechanisms  

E-Print Network [OSTI]

Basins, shales of Devonian age are commonly considered reservoir rocks I' or natural gas [Woodward, 1958; Lockett, 1968; Long, 1979; Gonzales and Johnson, 1985], Economic gas production from the Devonian shales of these basins is associated...] and slates [Donath, 1961], may be expected to be weak. Finally, Microstructural studies of deformed shales have been restricted by optical resolution, and the role of crystal plasticity in clays may have been overlooked. Results for the brittle and semi...

Ibanez, William Dayan

1993-01-01T23:59:59.000Z

248

Depositional environment of the Caballos Formation, San Francisco field, Neiva sub-basin, Upper Magdalena Valley, Colombia  

E-Print Network [OSTI]

to form the Paleo-Andes, which were exposed during the early or middle Devonian. The Andean region then underwent subsidence, which persisted to the end of the Paleozoic, while the eastern Llanos Platform remained emergent during the Devonian... shale, limestone, and sandstone towards the north, east, and southward. These Cretaceous deposits reach a total thickness of 12, 000 m. During a pre-Albian tectonic phase, the eastern part of the east Andean region was uplifted, the western part...

Sneider, John Scott

1988-01-01T23:59:59.000Z

249

Analysis of macroscopic fractures on Teton anticline, Northwestern Montana  

E-Print Network [OSTI]

1817 &UNCONFORMITY 174 &UNCONFORMITY 366 &UNCONFORMITY 286 &UNCONFORMITY 1536 &UNCONFORMITY 2100 Figure 4. Stratigraphy of the Sawtooth thrust province. these rocks from the thinner, shallow-marine Devonian carbonate ~ocks above. Another... minor unconformity separates the Devonian from the Lower Mississippian (Kinderhookian and Osagean series). Mississippian rocks represent a stable shelf environment with the oresence of 366 meters of shallow marine dolomites and limestones in the area...

Sinclair, Steven W.

1980-01-01T23:59:59.000Z

250

Wrench faulting and cavity concentration ; Dollarhide Field, Andrews County, Texas  

E-Print Network [OSTI]

Tectonics of the Central Basin Platform During the Early Paleozoic, North America's passive southern margin enabled carbonate and siliceous rocks to infill the Tobosa Basin, or what is now the permian Basin (Galley, 1958; Hills, 1972; Yang and Dorobek...-Guadalupian stratigraphy of the Dollarhide Field. limestones, dolomites and cherts except for the Ordovician Simpson Group. The Woodford Shale (Upper Devonian-Lower Mississippian) is organically rich and the probable source rock for the Devonian and Lower Permian...

Dygert, Todd Charles

1992-01-01T23:59:59.000Z

251

Supplement to Echinodermata Articles 8-10  

E-Print Network [OSTI]

, Michigan, Laudon coll., Esso Prod. Research Co. Ddx Wanakah Shale Member, Ludlowtalle Formation, Hamilton Group, Erian, Middle Devonian; on 18-mile Creek near bridge on old Lakeshore Road near Lake Erie southwest of Buffalo, Erie County, New York. Jeffords..., New York. W. F. Berry coll., Univ. Kansas Paleont. Inst. Dib Wanakah Shale Member (upper part), Ludlotvville Formation, Hamilton Group,Erian,Middle Devonian; cut on N.Y. 63 about 2 miles southeast of East Bethany, Genessee County, New York. W. F. Berry...

Moore, R. C.; Jeffords, Russell M.; Miller, T. H.

1968-01-01T23:59:59.000Z

252

Workshop on gas potential of New Albany shale held in conjunction with the 1995 Ioga meeting in Evansville, Indiana on March 1, 1995. Topical report  

SciTech Connect (OSTI)

This workshop is intended to provide an overview of the organic lithofacies, organic carbon content, thermal maturity, and gas potential of the Devonian and Mississippian New Albany Shale in the Illinois Basin. In addition, the reservoir characteristics and completion technology for productive organic-rich Devonian shales in the Michigan and Appalachian Basins are also reviewed. Emphasis is being placed on how proven technologies together with appropriate geologic and geochemical information can be used to explore for gas in the New Albany Shale.

NONE

1996-01-01T23:59:59.000Z

253

PrimeEnergy/DOE/GRI slant well. Final report  

SciTech Connect (OSTI)

This report presents final results of the Sterling Boggs 1240 slant well. Objectives of the project were (1) to test the potential for improved recovery efficiency in a fractured Devonian Shale reservoir from a directionally drilled well, (2) to perform detailed tests of reservoir properties and completion methods, and (3) to provide technology to industry which may ultimately improve the economics of drilling in the Devonian Shale and thereby stimulate development of its resources.

Drimal, C.E.; Muncey, G.; Carden, R.

1991-12-01T23:59:59.000Z

254

PrimeEnergy/DOE/GRI slant well  

SciTech Connect (OSTI)

This report presents final results of the Sterling Boggs 1240 slant well. Objectives of the project were (1) to test the potential for improved recovery efficiency in a fractured Devonian Shale reservoir from a directionally drilled well, (2) to perform detailed tests of reservoir properties and completion methods, and (3) to provide technology to industry which may ultimately improve the economics of drilling in the Devonian Shale and thereby stimulate development of its resources.

Drimal, C.E.; Muncey, G.; Carden, R.

1991-12-01T23:59:59.000Z

255

Water management practices used by Fayetteville shale gas producers.  

SciTech Connect (OSTI)

Water issues continue to play an important role in producing natural gas from shale formations. This report examines water issues relating to shale gas production in the Fayetteville Shale. In particular, the report focuses on how gas producers obtain water supplies used for drilling and hydraulically fracturing wells, how that water is transported to the well sites and stored, and how the wastewater from the wells (flowback and produced water) is managed. Last year, Argonne National Laboratory made a similar evaluation of water issues in the Marcellus Shale (Veil 2010). Gas production in the Marcellus Shale involves at least three states, many oil and gas operators, and multiple wastewater management options. Consequently, Veil (2010) provided extensive information on water. This current study is less complicated for several reasons: (1) gas production in the Fayetteville Shale is somewhat more mature and stable than production in the Marcellus Shale; (2) the Fayetteville Shale underlies a single state (Arkansas); (3) there are only a few gas producers that operate the large majority of the wells in the Fayetteville Shale; (4) much of the water management information relating to the Marcellus Shale also applies to the Fayetteville Shale, therefore, it can be referenced from Veil (2010) rather than being recreated here; and (5) the author has previously published a report on the Fayetteville Shale (Veil 2007) and has helped to develop an informational website on the Fayetteville Shale (Argonne and University of Arkansas 2008), both of these sources, which are relevant to the subject of this report, are cited as references.

Veil, J. A. (Environmental Science Division)

2011-06-03T23:59:59.000Z

256

Module 5: Fuel Cell Systems | Department of Energy  

Energy Savers [EERE]

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Office of Inspector General Office0-72.pdfGeorgeDoesn't32Department of Energy Modular CHP System for Utica

257

Mohammad Khan | Department of Energy  

Energy Savers [EERE]

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Office of Inspector General Office0-72.pdfGeorgeDoesn't32Department of Energy Modular CHP System for UticaMohammad

258

Simulator for unconventional gas resources multi-dimensional model SUGAR-MD. Volume I. Reservoir model analysis and validation  

SciTech Connect (OSTI)

The Department of Energy, Morgantown Energy Technology Center, has been supporting the development of flow models for Devonian shale gas reservoirs. The broad objectives of this modeling program are: (1) To develop and validate a mathematical model which describes gas flow through Devonian shales. (2) To determine the sensitive parameters that affect deliverability and recovery of gas from Devonian shales. (3) To recommend laboratory and field measurements for determination of those parameters critical to the productivity and timely recovery of gas from the Devonian shales. (4) To analyze pressure and rate transient data from observation and production gas wells to determine reservoir parameters and well performance. (5) To study and determine the overall performance of Devonian shale reservoirs in terms of well stimulation, well spacing, and resource recovery as a function of gross reservoir properties such as anisotropy, porosity and thickness variations, and boundary effects. The flow equations that are the mathematical basis of the two-dimensional model are presented. It is assumed that gas transport to producing wells in Devonian shale reservoirs occurs through a natural fracture system into which matrix blocks of contrasting physical properties deliver contained gas. That is, the matrix acts as a uniformly distributed gas source in a fracture medium. Gas desorption from pore walls is treated as a uniformly distributed source within the matrix blocks. 24 references.

Not Available

1982-01-01T23:59:59.000Z

259

Geometry and styles of displacement transfer, eastern Sun River Canyon Area, Sawtooth Range, Montana  

E-Print Network [OSTI]

rocks of this area. A simplified stratigraphic column for the study area is given in Figure 7. The oldest rocks exposed in the study area belong to the Devonian age Jefferson Formation. Mudge (1972a) assigns two members, a lower member... that "blind" thrusts which place Devonian strata on Cretaceous strata exist in the subsurface east of the apparent eastern edge of the Sawtooth Range. The F 13-21 Serial Federal well lies roughly 5 km (3 mi) northeast of the study area (Figure 11...

Goldburg, Barbara Louise

1984-01-01T23:59:59.000Z

260

Paleoenvironmental analysis of the lower Mississippian Caballero Formation and the Andrecito member of the Lake Valley Formation in the northern Sacramento Mountains Otero County, New Mexico  

E-Print Network [OSTI]

. It 2 11 a )3. 3 k ) a ay. B. Bh ~Zhy burrows in uppermost-Caballero strata. C. Shows Devonian black-shale-filled channel in Marble Canyon. Cut inta yellowish Sly Gap limestone. Channel is forty feet (12. Z m) thick... along this unconformity. A 40 foot (12. 2 m) thick shale-filled channel is found here. This channel cuts into the Devonian-aged Sly Gap nodular-limestone (Pray, 1961; Dekeyser, 1978). The shale-fill may be equivalent to the Percha Formation (Pray...

Blount, William Markham

1985-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


261

The Letters of Claudius Terentianus and the New Testament: insights and observations on epistolary themes  

E-Print Network [OSTI]

all else I pray for your health and success. 32 P. Mich. 467.3-4: an[te omn]ia opto te] fortem et h[i]larem [e]t salvom mihi esse cum nostris omn[ibus]: Before all else, I pray that you be strong and cheerful and well, together with our entire... the pilot, Fronto together with his family, Sempronius Italicus, Publicius, Severinus, your colleague Marcellus, and Lucius. Greet Serenus the clerk together with his family. Greet all our comrades. Farewell. (P. Mich. 468:46-63) These greetings serve...

Head, Peter M.

262

Tulsa Metropolitan Area Destination 2030 Long Range Transportation Plan  

E-Print Network [OSTI]

OP 151 OP 20 tu 64 ??? 44 ??? 244 ??? 44 ??? 44 tu 75 tu 412 tu 75A tu 169 tu 64 Cherokee Industrial Park Tulsa Airport Area 21st & Utica Corridor BA Expressway & US 169 Corridor South Yale Corridor Port of Catoosa 116th 106th 126th Pine 36th 146th... International Airport Port of Catoosa Johnston's Port 33 116th 106th 126th Pine 36th 146th 166th 56th Uni o n 46th 171st Y a l e 3 3 r d W 161st P e o r i a M i n g o 1 2 9 t h W E l w o o d Apache 1 2 9 t h Admiral 151st 8 1 s t W L e w i s G a r n e t t 9 7...

Indian Nations Council of Governments

263

Synthetic fuels from US oil shales: a technical and economic verification of the HYTORT Process. Quarterly report, January 1-March 31, 1980  

SciTech Connect (OSTI)

Objective is to demonstrate the technical and economic feasibility of the HYTORT process for both Eocene and Devonian shales. The program is divided into five major task areas: laboratory program, bench-scale program, process development unit tests, process environmental assessment, and process design and economics. (DLC)

None

1980-06-01T23:59:59.000Z

264

Deformation in ramp regions of thrust faults: experiments with rock models  

E-Print Network [OSTI]

&a&es of? the L'ona- sauga G& oup (I&liddl e and Upper Camj&rfan) and Lhe Chattanooga Shale (Devonian ar d tfississippian), and transverse tr& bed?ini; in ti e more "cr&mpetrr t" sir ata. 1 he final conf igiuration, accordirg to Rich, is sho:in scheim...

Morse, James Donald

1978-01-01T23:59:59.000Z

265

ILLINOIS STATE GEOLOGICAL SURVEY Interior Cratonic Basins, 1991, edited by M. W. Leighton, D. R. Kalata, D. F. Oltz,  

E-Print Network [OSTI]

) by that year. Significant quantities of petroleum are produced from fields widely separated from known oil sources. These oils apparently migrated laterally over paths of many tens of miles and perhaps more than reservoirs more than 125 mi (200 km) from the basin's depocenter, were derived from Devonian source rocks

Bethke, Craig

266

Hummingbird structure in southeastern Saskatchewan  

SciTech Connect (OSTI)

Saskatchewan's first Devonian oil pool was discovered September 1966, at Hummingbird, 45 mi (72 km) southwest of Weyburn, Saskatchewan. The Hummingbird structure, located on the northwest flank of the Williston basin, is domal is nature and covers approximately 1 mi/sup 2/ (2.6 km/sup 2/). Oil production is from two zones. The Ratcliffe Member of the Mississippian Charles Formation produces from an algal and bioclastic limestone averaging 49 ft (15 m) thick. The Devonian Birdbear Formation produces from a finely crystalline vuggy dolomite averaging 56 ft (17 m) thick. The Hummingbird structure is a sedimentary structure resulting from multiple-stage salt solution and collapse. Recurring local solution of Middle Devonian Prairie Evaporite during Late Devonian and Early Mississippian time resulted in collapse of overlying strata and deposition of compensating thicknesses of Souris River, Duperow, and Bakken sediments. Between Mississippian and Cretaceous time, solution of Prairie Evaporite in the surrounding area caused collapse of all super-Prairie evaporite beds. The extra Souris River, Duperow, and Bakken strata at Hummingbird created the structure. Vertical migration of formation waters along a high-angle fault is suggested as the cause of the local salt solution at Hummingbird.

Smith, D.D.

1985-05-01T23:59:59.000Z

267

Deep-Sea Research II 54 (2007) 13121326 Oxidation of detrital pyrite as a cause for Marcasite Formation  

E-Print Network [OSTI]

Shale of New York State and three examples from sequence boundaries in the New Albany Shale of Kentucky 10 July 2007 Abstract Late Devonian black shale successions in the eastern US contain numerous; Black shale 1. Introduction Flooding surfaces and sequence boundaries in marine mudstone successions

Polly, David

268

Australian Journal of Earth Sciences (1988) 35, 223-230 Shear-zone deformation in the Yackandandah Granite,  

E-Print Network [OSTI]

Granite, northeast Victoria Michael Sandiford, 1 Stuart F. Martin2 and Eric M. Lohe2 lDepartment o mid-Devonian age resulted in the formation ofa ductile shear zone in the granite, termed the Kiewa shear zone. Displacement of granite boundaries and shear-zone fabrics, including excellently developed s

Sandiford, Mike

269

Correlation and Stratigraphic Analysis of the Bakken and Sappington Formations in Montana  

E-Print Network [OSTI]

The Upper Devonian-Lower Mississippian (Late Fammenian-Tournaisian) Bakken Formation in the Williston Basin is one of the largest continuous oil fields in the U.S. The upper and the lower shale members are organic rich source rocks that supplied oil...

Adiguzel, Zeynep 1986-

2012-09-24T23:59:59.000Z

270

A Brief History of Time John C. Baez, September 23, 2004  

E-Print Network [OSTI]

-- Permian-Triassic extinction. 90% of all species died out! 313 million years ago -- First reptiles. 370 million years ago -- Devonian extinction. 70% of marine species died out! First amphibians, trees. 395. 35,000 years ago -- Invention of the calendar, extinction of Neanderthalers. 600,000 years ago

Baez, John

271

Pressure-transient test design in tight gas formations  

SciTech Connect (OSTI)

This paper outlines a procedure for pre- and postfracture pressure-transient test design in low-permeability (tight) gas formations. The procedures proposed are based on many years' experience in evaluating low-permeability formations, and particularly on recent experience with Gas Research Inst. (GRI) programs in eastern Devonian gas shales and in western tight-gas formations.

Lee, W.J.

1987-10-01T23:59:59.000Z

272

A Systems Approach to Identifying Exploration and Development Opportunities in the Illinois Basin: Digital Portifolio of Plays in Underexplored Lower Paleozoic Rocks  

SciTech Connect (OSTI)

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 Albany Shale is regarded as the source rock for petroleum in Silurian and younger strata in the Illinois Basin and has potential as a petroleum reservoir. Field studies of reservoirs in Devonian strata such as the Geneva Dolomite, Dutch Creek Sandstone and Grassy knob Chert suggest that there is much additional potential for expanding these plays beyond their current limits. These studies also suggest the potential for the discovery of additional plays using stratigraphic concepts to develop a subcrop play on the subkaskaskia unconformity boundary that separates lower Devonian strata from middle Devonian strata in portions of the basin. The lateral transition from Geneva Dolomite to Dutch Creek Sandstone also offers an avenue for developing exploration strategies in middle Devonian strata. Study of lower Devonian strata in the Sesser Oil Field and the region surrounding the field shows opportunities for development of a subcrop play where lower Devonian strata unconformably overlie Silurian strata. Field studies of Silurian reservoirs along the Sangamon Arch show that opportunities exist for overlooked pays in areas where wells do not penetrate deep enough to test all reservoir intervals in Niagaran rocks. Mapping of Silurian reservoirs in the Mt. Auburn trend along the Sangamon Arch shows that porous reservoir rock grades laterally to non-reservoir facies and several reservoir intervals may be encountered in the Silurian with numerous exploration wells testing only the uppermost reservoir intervals. Mapping of the Ordovician Trenton and shallower strata at Centralia Field show that the crest of the anticline shifted through geologic time. This study illustrates that the axes of anticlines may shift with depth and shallow structure maps may not accurately predict structurally favorable reservoir locations at depth.

Beverly Seyler; David Harris; Brian Keith; Bryan Huff; Yaghoob Lasemi

2008-06-30T23:59:59.000Z

273

Displacements required during multiple drapefolding along the northwest Bighorn Mountain front, Wyoming  

E-Print Network [OSTI]

folds of the eastern Uinta Mountains (Cook and Stearns, 1975). Shale sections also flow and thin easily and Vaughn (1976) reports consid. erable I;hinning in the Mesozoic fine-grained clastic rocks (Permian thru Jurassic) as they drape over... deposited on the continental shelf bor- dering the Paleozoic geosyncline. The Ordovicain Bighorn Dolomite is a massive, thick bedded dolomite, while the Devonian Jefferson-Three Fork Formation is a thin-bedded limestone interbedded wi. th thin shale...

Tirey, Martha Margaret

1978-01-01T23:59:59.000Z

274

The nature of the Heart Mountain fault in the vicinity of Dead Indian Hill, Park County, Wyoming  

E-Print Network [OSTI]

Mountain thrust blocks consti- tuted a very limited strat1graphic interval, consisting of Ordovician B1ghorn Dolomite, undifferentiated dolomi tes, 1 1mestones and shales of Devonian age (Jefferson-Three Forks Formations) and the Mississippian Madison... of the thrust the transgress1ve fault zone and reports the slope of the transgressive fault to be approximately 10 degrees. A field study was conducted in the area of the transgressive fault in an attempt to better understand the mechanics of how...

Sungy, Eugene Donald

1977-01-01T23:59:59.000Z

275

Geology of the Pontotoc Northwest area, San Saba and Mason Counties, Texas  

E-Print Network [OSTI]

age. i crinoidal limestone of Early Mississippian age, underlying the Barnett shale, was reported by Roundy, Girty, and Goldman (1926). Sellards (1932) assigned the name Chappel to the unit. Jones (1929) described the stratigraphic units along... of Texas. Small occurrences of rooks of Devonian age were discovered and described by Barnes, Cloud, and Warren (1945). The age determination was based on fossils contained in the rocks. Decker (1945) studied the graptolites of the Vilberns forma- tion...

Jennings, Albert Ray

1960-01-01T23:59:59.000Z

276

Structural relations along the western end of the Arrowhead Fault, Muddy Mountains, Nevada  

E-Print Network [OSTI]

, resembling "drag" effects related to horizontal movement on the Arrowhead fault, are interpreted as the re- sult of a drape-folded fold. The Summit thrust, a local northwesterly trending fault at the eastern end of the study area, is interpreted... Bonanza King Formation Dunderb erg Shale Buffington Formation Ordovician System Monocline Valley Formation Devonian System Muddy Peak Limestone Mississippian Series Rogers Spring Limestone vii xiii 12 12 12 12 13 1) 23 25 25 26 26 26...

Temple, Vernon James Jay

1977-01-01T23:59:59.000Z

277

Structural geology of the Irons Fork - North Fork Creek area, Lake Ouachita, Arkansas  

E-Print Network [OSTI]

by the Missouri Mountain shale, which is Silurian in age. The Blaylock sandstone, which is between the Polk Creek and Missouri Mount- ain shales in the southern Ouachitas, is absent in the study area. The Missouri Mountain contains olive brown to buff colored... estimated for the Missouri Mountain (Haley snd others, 1973b). Devonian ? Mississi ian S stem Arkansas Hovaculite. The Arkansas Novaculite overlies the Missouri Mountain shale. It is one of the predominant formations in the study 12 area, the other...

White, Marjorie Ann

1980-01-01T23:59:59.000Z

278

Environment of deposition of the Pennsylvanian Bartlesville Sandstone, Labette County, Kansas  

E-Print Network [OSTI]

were available for study. Published reports on the Bartlesville Sandstone in Kansas, Missouri, and Oklahoma (Bass, 1936, Howe, 1956j Weirich, 1953; Hayes, 1963; Pharos, 1969; Visher, Saitta B. and Phares, 1971) provided additional information..., with the Chautauqua Arch forming a connection between the two uplifts (Figure 2). By Late Devonian time the Chautaugua Arch was no longer active, Eastern Kansas was divided by the Bourbon Arch into the Forest City and Cherokee Basins in Late Mississippian time...

Johnson, Charles Truman Lars

1973-01-01T23:59:59.000Z

279

Structural analysis of the western Llano uplift with emphasis on the Mason fault  

E-Print Network [OSTI]

of the Marble Falls and Smithwick Formations 52 10. Schematic tectonic cross section across the Llano region during the Ouachita orogeny 55 11. Simplified geologic map of Llano region 59 12. Geologic map of Precambr i an structur e in Mason area 61 13... Formation Marble Falls Formation upper member unconformity Morrowian Series Marble Falls Formation lower member Mississippian System Barnett Formation Chappel Formation Devonian System Houy Formation Ives Breccia neon for mf ty Ordovician...

Becker, Joseph Ernest

1985-01-01T23:59:59.000Z

280

Environment of deposition and reservoir characteristics of Lower Pennsylvanian Morrowan sandstones, South Empire field area, Eddy County, New Mexico  

E-Print Network [OSTI]

New Mexico. The Lower and Middle Morrow intervals in the South Empire field area consist of stacked, fluvial to deltaic sandstones that are interbedded with thin limestones. An understanding of the complex, interfingering relation- ships... of the Tobosa basin, the thinning of Ordovician sediments suggests the initiation of uplift on the Diablo Platform. A period of quiescence punctuated by episodes of regional uplift existed from the late Ordovician to the late Devonian-early Mississ- ippian...

Lambert, Rebecca Bailey

1986-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


281

Study seeks to boost Appalachian gas recovery  

SciTech Connect (OSTI)

Ashland Exploration Inc. and the Gas Research Institute (GRI) are trying to find ways to increase gas recovery in the Appalachian basin. They are working together to investigate Mississippian Berea sandstone and Devonian shale in a program designed to achieve better understanding and improved performance of tight natural gas formations in the area. This paper reports that three wells on Ashland Exploration acreage in Pike County, Ky., are involved in the research program. Findings from the first two wells will be used to optimize evaluation and completion of the third well. The first two wells have been drilled. Drilling of the third well was under way at last report. Ashland Exploration has been involved with GRI's Devonian shale research since 1988. GRI's initial focus was on well stimulation because Devonian shale wells it reviewed had much lower recoveries than could be expected, based on estimated gas in place. Research during the past few years was designed to improve the execution and quality control of well stimulation.

Not Available

1992-07-20T23:59:59.000Z

282

Williston Basin subsidence and sea level history: Chronological and lithofacies constraints  

SciTech Connect (OSTI)

The intent is to use lithofacies information to identify the top-driven components of sediment accumulation-depositional environments, sediments supply, compaction, sediment and water load. Physical carbonate stratigraphy is used to determine sediment accumulation corrections. Physical stratigraphic geometric patterns are used to estimate the original thicknesses of dissolved salts and to determine absolute water depth. Seawater strontium chronostratigraphy constrains the ages and paleo-oceanographic setting of Devonian-Mississippian strata. The measured strontium stratigraphy can be used for correlation, age assignment and diagentic study. Removing sediment compaction, sediment/water load effects and using the newly derived Devonian-Mississippian chronostratigraphy to examine the behavior of the Williston Basin reveals a number of facts. (1) Temporal and spatial variation in the surficial components of sediment accumulation is significant and, unless removed, obscures tectonic subsidence and sea-level change patterns. (2) Both the corrected tectonic subsidence/sea level record and lithofacies patterns of the Devonian Williston Basin show flexural or in-plane stress interference reflecting plate boundary reorganization along the near edge of the Paleozoic North American craton, culminating the Antler orogeny. (3) The tectonic subsidence and sea level change record of the Williston Basin which has been corrected for sediment compaction, water and sediment load, has extremely linear subsidence through time. This is interrupted by changes in global sea level of 100-140 m over 25-35 my and apparent sea level change of 35-60 m over 2-4 my.

Lee Roark, C.K.

1989-01-01T23:59:59.000Z

283

Winnipegosis case history: Tableland Saskatchewan  

SciTech Connect (OSTI)

The geology and history of exploration in the Tableland area of southeast Saskatchewan will be reviewed in relation to a major Middle Devonian Winnipegosis oil discovery made in 1986 by Home Oil. Southern Saskatchewan is underlain by the northern third of the Williston basin. Although rich oil deposits have been found in the Devonian of the basin on the American side, dry holes have been the rule in Saskatchewan except for the Hummingbird Upper Devonian Birdbear discovery in 1966. The long history of failures in the Winnipegosis Formation had led to a general reluctance in the industry to drill deep wells especially with today's lower crude prices. Based on geology, seismic data, and modeling, Home Oil drilled Tableland 08-22-002-09W2M in february 1986 and encountered an oil-bearing Winnipegosis reef. This well has the highest production rate of any well in Saskatchewan and is the first commercially significant Winnipegosis well in a basinal setting within the Williston basin. A state-of-the-art pseudo 3-D processing of all the existing 2-D seismic data was performed to aid in choosing development well locations. As a result of this discovery, deep exploration plays in southeast Saskatchewan are now being pursued aggressively by many companies.

Orr, N.E.; Martindale, W.

1988-02-01T23:59:59.000Z

284

Oil and gas developments in western Canada in 1987  

SciTech Connect (OSTI)

Exploratory drilling in western Canada increased by 21% in 1987 whereas total drilling increased by 32%. The seismic crew count increased 4% to 671 crew-months, and land expenditures increased 166% to $793 million. No major plays broke during 1987 in western Canada. The 2 major plays resulting from 1986 activity - Caroline, Alberta, and Tableland, Saskatchewan - continued to expand in 1987. By year end at Caroline, industry drilled 14 wells, which included 6 Swan Hills gas wells, 3 uphole gas wells, 3 wells standing or suspended, and 2 dry holes. The reserves for this field now are 17 billion m/sup 3/ of sales gas, 32 million m/sup 3/ of condensate, and 20 million MT of sulfur. At Tableland and surrounding areas, industry has drilled 11 oil wells and 16 dry holes. No overall reserve figures have been published for this play. In Alberta, operators had their best exploratory oil success in the Cretaceous Second White Specks and in the Devonian Nisku, Leduc, Gilwood, and Keg River; the best exploratory gas success was in the Cretaceous Viking and Paddy, and Devonian Nisku and Leduc. In British Columbia, gas drilling was successful in the Cretaceous of the Deep Basin, as well as in the Mississippian Kiskatinaw and the Triassic Halfway. In Saskatchewan, both the shallow Cretaceous gas play and the deep Devonian Winnipegosis oil play continued to expand, whereas in Manitoba the main exploration target was the Mississippian carbonates and Bakken Formation. The Northwest Territories, Beaufort Sea, and Arctic Islands had a poor year, with only 4 exploratory wells drilled - all dry holes. 7 figs., 10 tabs.

Portigal, M.H.; Creed, R.M.; Hogg, J.R.; Hewitt, M.D.

1988-10-01T23:59:59.000Z

285

Petroleum potential of lower and middle Paleozoic rocks in Nebraska portion of Mid-Continent  

SciTech Connect (OSTI)

Central North America during the Paleozoic was characterized by northern (Williston) and southern (Anadarko) depositional regimes separated by a stable Transcontinental arch. Nebraska lies on the southern flank of this arch and contains the northern zero edges of the lower and middle Paleozoic rocks of the southern regime. Most of these rocks are secondary dolomites with zones of excellent intercrystalline porosity. The Reagan-LaMotte Sandstones and the overlying Arbuckle dolomites are overlapped by Middle Ordovician rocks toward the Transcontinental arch. Rocks equivalent to the Simpson consist of a basal sand (St. Peter) and overlying interbedded gray-green shales and dolomitic limestones. An uppermost shale facies is present in the Upper Ordovician (Viola-Maquoketa) eastward and southward across Nebraska. The dolomite facies extends northward into the Williston basin. The Silurian dolomites, originally more widely deposited, are overlapped by Devonian dolomites in southeastern Nebraska. Upper Devonian rocks exhibit a regional facies change from carbonate to green-gray shale to black shale southeastward across the Mid-Continent. Mississippian carbonates overlap the Devonian westward and northward across the Transcontinental arch. Pennsylvanian uplift and erosion were widespread, producing numerous stratigraphic traps. Sands related to the basal Pennsylvanian unconformity produce along the Cambridge arch. Arbuckle, Simpson, Viola, and Hunton production is present in the Forest City basin and along the Central Kansas uplift. Although source rocks are scarce and the maturation is marginal, current theories of long-distance oil migration encourage exploration in the extensive lower and middle Paleozoic reservoirs in this portion of the Mid-Continent.

Carlson, M.P. (Univ. of Nebraska, Lincoln (USA))

1989-08-01T23:59:59.000Z

286

Geology of the Little Bluff Creek Area, Mason County, Texas  

E-Print Network [OSTI]

of the reseax'ch ax ea. A ccaxprehensive report on the Elle~ger gx'oup cx centxal Texas was written by Cloud and Pernea in 1+S~ the Canbrian, Devonian, and Pennsylvanian strata were discussed briefly. Plucxxer (lg$0) prepared a detailed xepOxt coverin...'ea range in age froa Precasbrian to Recent. Along the eastern extreaitiea of this area, Precaub! ian schist and gxanite are exposed. Upper Caabrian aandatonea, lijaeatonea, and shalea occur in seventy-five per cent of the research area. Cretaceous...

Mangum, Charles Roland

1960-01-01T23:59:59.000Z

287

Structural analysis and geologic history of the Cedar Fourche area, Lake Ouachita, Arkansas  

E-Print Network [OSTI]

of the Arkoma Basin, The deformed Paleozoic rocks to the south are onlapped by the updip exposure of Cretaceous and younger sed1ments of the Coastal Pla1n (Fig. 2}. Exposed Qrdovi c1an through Devonian-Mi ss1 ssippian rocks consist of black shales... Womble shales. The Ordo- v1ci an Bi gfork Formation is probably close to the 195 meter thick- ness reported by Oav1es and W1lliamson (1976), based on cross sections through the northern exposures 1n the study area (Plate 'I). This thi ckness...

Tucker, James William

1980-01-01T23:59:59.000Z

288

Geology of the South Mason County area, Texas  

E-Print Network [OSTI]

) visited the Central ~ region, studied the rocks, and established the Upper Cambric age of ths Potsdam gmup. To the Lower Cambrian strata Walcott gave the name Llano group. He assigned a pre-Potsdam age to the masses of granite in western Burnet County... of the strata as reported in ths First Annual Report He commented on the provisional existence-a designation which he inferred may not hold after the characteristic fossils are identifisd- of limited areas of Devonian rocks, Special emphasis was given...

Alexander, William Luther

1952-01-01T23:59:59.000Z

289

Gravity interpretation of the northern Overthrust Belt, Idaho and Wyoming  

E-Print Network [OSTI]

sequence thickness westward from about 15 miles (2a. l km) east of the Idaho-Wyoming State line, to a site of maximum deposition somewhere in the west (Armstrong and Oriel, 1965). In western Wyoming, Drdovic-ian rocks are represented by the Upper... 1n southeastern Idaho by the Laketown Dolomite. The lim1ted geoqraph1c extent of the Silurian is considered to be the result of subsequent erosion rather than non-deposition (Armstrong and Oriel, 1965). In western Wyoming, the Devonian age rocks...

Silver, Wendy Ilene

1979-01-01T23:59:59.000Z

290

Research results from the Ashland Exploration, Inc., Ford Motor Company 80 (COOP 2) well, Pike County, KY. Topical report, October 1991-November 1992  

SciTech Connect (OSTI)

The report summarizes the work performed on the Ashland Exploration, Inc. (AEI) Ford Motor Company 80 (COOP 2) well in Pike County, KY. The COOP 2 was the second well in a three-well research project being conducted by GRI in eastern Kentucky targeting both the Devonian Shales and the Berea Sand; the FMC 80 focused on the Berea. The primary objective of the research was to use and transfer technologies developed in GRI`s Tight Gas Sands and Gas Shales programs to evaluate the Berea in Pike Co., KY.

Frantz, J.H.; Lancaster, D.E.

1993-04-01T23:59:59.000Z

291

The development of early terrestrial ecosystems  

E-Print Network [OSTI]

,575-599. Burgess, N.D. & Edwards, D. (1991). Classification of uppermost Ordovician to Lower Devonian tubular and filamentous macerals from the Anglo-Welsh Basin. Botanical Journal of the Linnean Society 106,41-66. Campbell, S.E. (1979). Soil stabilization...., Massa, D. & Boucot A J . (1982). Caradocian land plant microfossils from Libya. Geology 10.197-201. Gray, J., Theron, J.N. & Boucot, A J . (1986). Age of the Cedarberg Formation, South Africa and early land plant evolution. Geological Magazine 123...

Selden, Paul A.; Edwards, Dianne

1993-01-01T23:59:59.000Z

292

Review of {sup 222}Rn in natural gas produced from unconventional sources  

SciTech Connect (OSTI)

A review of the literature on trace radioactivity in natural gas and natural gas products has been performed and the consequent radioactivity concentrations and dose rates due to natural radioactive elements in natural gas produced from Devonian shale wells, western tight gas sands, geo-pressurized aquifiers and coal beds have been studied. Preliminary data on {sup 222}Rn concentrations from these energy sources fall within the range observed for more conventional sources. Gas produced from reservoirs with higher than average natural /sup 238/U higher than average levels of {sup 222}Rn. Massive fracturing techniques do not appear to raise the relative concentration of radon in natural gas.

Gogolak, C.V.

1980-11-01T23:59:59.000Z

293

Hunton Group core workshop and field trip  

SciTech Connect (OSTI)

The Late Ordovician-Silurian-Devonian Hunton Group is a moderately thick sequence of shallow-marine carbonates deposited on the south edge of the North American craton. This rock unit is a major target for petroleum exploration and reservoir development in the southern Midcontinent. The workshop described here was held to display cores, outcrop samples, and other reservoir-characterization studies of the Hunton Group and equivalent strata throughout the region. A field trip was organized to complement the workshop by allowing examination of excellent outcrops of the Hunton Group of the Arbuckle Mountains.

Johnson, K.S. [ed.

1993-12-31T23:59:59.000Z

294

Exploration model for shallow Silurian (Kankakee) carbonate reservoirs in western Illinois  

SciTech Connect (OSTI)

Reservoirs in shallow (600-650 ft deep) basal Silurian Kankakee carbonates at Buckhorn consolidated, Siloam, and Kellerville oil fields in western Illinois have produced nearly 2 million bbl of oil, but were developed essentially by random drilling. A new exploration model that combines lithologic studies and isopach mapping has been developed at the Illinois State Geological Survey. Isopach mapping of Silurian and Devonian rocks between an organic facies in the Mississippian-Devonian New Albany Shale and the top of the Ordovician Maquoketa Shale reveals thickened sequences that coincide with most of the oil fields. These thickened intervals apparently reflect subtle paleovalleys eroded into the Maquoketa shale during the Ordovician-Silurian hiatus. During the initial Silurian marine transgression, these paleovalleys at the base of the Kankakee were filled with carbonates to form the thickened sequences. Differential erosion at the top of the Kankakee does not satisfactorily explain the locally thickened sequences in the Kankakee. Lithologic studies suggest that subsurface fluid flows concentrated along these paleovalleys contributed to subsequent diagenesis of valleyfill carbonates. Diagenetic alteration of these carbonates resulted in development of basal Kankakee reservoirs within the paleovalleys. This concept of Kankakee reservoirs occurring within paleovalleys at the Ordovician-Silurian unconformity is a new exploration model that can aid in the search for similar traps in western Illinois.

Crockett, J.E.; Seyler, B.J.; Whitaker, S.

1987-09-01T23:59:59.000Z

295

Deposition and diagenesis of a cratonic Silurian platform reef, Pipe Creek Jr. , Indiana  

SciTech Connect (OSTI)

Petrographic and geochemical characteristics of the Pipe Creek Jr. paragenesis record the stratigraphic and burial evolution of the cratonic Silurian platform of Indiana during Late Silurian to Pennsylvanian. A variety of several diagenetic fluids acting over geological time affected the reef. The paragenetic sequence is as follows: (1) precipitation of turbid, fibrous, blotchy cathodoluminescent (CL) cement; (2) dolomitization of mud-rich facies; (3) precipitation of clear, zoned CL equant calcite cements; (4) fracturing and karst formation, partially filled by geopetal silt and sandstone; (5) precipitation of clear, dull CL, ferroan to nonferroan equant calcite cement, ferroan dolomite overgrowth and equant dolomite cement in moldic porosity, caves and fractures; (6) microdissolution and hydrocarbon emplacement; and (7) stylolitization. Carbonate grew and fibrous cements precipitated in an open marine environment. During Late Silurian an increasingly restricted environment stopped reef growth and dolomite replaced mud-rich faces. The reefs were then subaerially exposed and two meteoric cement sequences, non-luminescent to bright luminescent, precipitated prior to Mid-Devonian fracture-controlled karsting. Caves and fractures crosscut former cement stages and were filled by sandstones. Later, the platform was buried by the late Mid-Devonian organic-rich New Albany Shale, and clear, dull CL calcite cement and ferroan dolomite precipitated. Hydrocarbon migration postdates all cements and created minor moldic porosity and predates stylolitization.

Simo, A.; Lehmann, P.

1988-01-01T23:59:59.000Z

296

Geology and hydrocarbon potential of the Hamada and Murzuq basins in western Libya  

SciTech Connect (OSTI)

The Hamada and Murzuq intracratonic basins of western Libya form a continuation of the Saharan basin which stretches from Algeria eastward into Tunisia and Libya. The tectonics and sedimentology of this region have been greatly influenced by the Caledonian and Hercynian orogenies. Northwest- and northeast-trending faults are characteristic of the broad, shallow basins. The Cambrian-Ordovician sediments are fluvial to shallow marine. The Silurian constitutes a complete sedimentary cycle, ranging from deep marine shales to shallow marine and deltaic sediments. The Devonian occupies a unique position between two major orogenies. The Mesozoic strata are relatively thin. The Triassic consists of well-developed continental sands, whereas the Jurassic and Cretaceous sediments are mainly lagoonal dolomites, evaporites, and shales. Silurian shales are the primary source rock in the area. The quality of the source rock appears to be better in the deeper part of the basin than on its periphery. The Paleozoic has the best hydrocarbon potential. Hydrocarbons have also been encountered in the Triassic and Carboniferous. In the Hamada basin, the best-known field is the El Hamra, with reserves estimated at 155 million bbl from the Devonian. Significant accumulations of oil have been found in the Silurian. Tlacsin and Tigi are two fields with Silurian production. In the Murzuq basin the Cambrian-Ordovician has the best production capability. However, substantial reserves need to be established before developing any field in this basin. Large areas still remain unexplored in western Libya.

Kirmani, K.U.; Elhaj, F.

1988-08-01T23:59:59.000Z

297

Depositional sequence evolution, Paleozoic and early Mesozoic of the central Saharan platform, North Africa  

SciTech Connect (OSTI)

Over 30 depositional sequences have been identified in the Paleozoic and lower Mesozoic of the Ghadames basin of eastern Algeria, southern Tunisia, and western Libya. Well logs and lithologic information from more than 500 wells were used to correlate the 30 sequences throughout the basin (total area more than 1 million km{sup 2}). Based on systematic change in the log response of strata in successively younger sequences, five groups of sequences with distinctive characteristics have been identified: Cambro-Ordivician, Upper Silurian-Middle Devonian, Upper Devonian, Carboniferous, and Middle Triassic-Middle Jurassic. Each sequence group is terminated by a major, tectonically enhanced sequence boundary that is immediately overlain (except for the Carboniferous) by a shale-prone interval deposited in response to basin-wide flooding. The four Paleozoic sequence groups were deposited on the Saharan platform, a north facing, clastic-dominated shelf that covered most of North Africa during the Paleozoic. The sequence boundary at the top of the Carboniferous sequence group is one of several Permian-Carboniferous angular unconformities in North Africa related to the Hercynian orogeny. The youngest sequence group (Middle Triassic to Middle Jurassic) is a clastic-evaporite package that onlaps southward onto the top of Paleozoic sequence boundary. The progressive changes from the Cambrian to the Jurassic, in the nature of the Ghadames basin sequences is a reflection of the interplay between basin morphology and tectonics, vegetation, eustasy, climate, and sediment supply.

Sprague, A.R.G. (Exxon Production Research Co., Houston, TX (United States))

1991-08-01T23:59:59.000Z

298

Stratigraphic and structural distribution of reservoirs in Romania  

SciTech Connect (OSTI)

In Romania, there are reservoirs at different levels of the whole Cambrian-Pliocene interval, but only some of these levels have the favorable structural conditions to accumulate hydrocarbons in commercial quantities. These levels are the Devonian, Triassic, Middle Jurassic, Lower Cretaceous (locally including the uppermost Jurassic), Eocene, Oligocene-lower Miocene, middle and upper Miocene, and Pliocene. The productive reservoirs are represented either by carbonate rocks (in Devonian, Middle Triassic and uppermost Jurassic-Lower Cretaceous) or by detrital rocks (in Lower and Upper Triassic, Middle Jurassic, Eocene, Oligocene, Miocene, and Pliocene). From the structural point of view, the Romanian territory is characterized by the coexistence both of platforms (East European, Scythian, and Moesian platforms) and of the strongly tectonized orogenes (North Dobrogea and Carpathian orogenes). Each importance crust shortening was followed by the accumulation of post-tectonic covers, some of them being folded during subsequently tectonic movements. The youngest post-tectonic cover is common both for the platforms (foreland) and Carpathian orogene, representing the Carpathian foredeep. Producing reservoirs are present in the East European and Moesian platforms, in the outer Carpathian units (Tarcau and Marginal folds nappes) and in certain post-tectonic covers which fill the Carpathian foredeep and the Transylvanian and Pannonian basins. In the platforms, hydrocarbons accumulated both in calcareous and detrital reservoirs, whereas in the Carpathian units and in their reservoirs, whereas in the Carpathian units and in their post-tectonic covers, hydrocarbons accumulated only in detrital reservoirs.

Stefanescu, M.O. (Inst. of Geology and Geophysics, Bucharest (Romania))

1991-08-01T23:59:59.000Z

299

Petrographic, geochemical, and paleohydrologic evidence of nature of petroleum migration in Illinois basin  

SciTech Connect (OSTI)

Detailed studies of the petrography and geochemistry of petroleum source rocks, the geochemistry of petroleum accumulations, and the paleohydrology of the Illinois basin suggest an episode of long-range migration of Devonian-sourced petroleum during a period of regional ground water flow. Petrographic analyses of samples of the New Albany Shale group (Devonian/Mississippian) were used to define lateral and vertical variation in composition and thermal maturity of organic matter within the basin. These data delineate likely New Albany Shale group petroleum source areas. GC, GCMS, and carbon isotopic analyses of thermally mature New Albany Shale in southeastern Illinois and Silurian-reservoired petroleum samples from central Illinois were used in making oil-oil and oil-source rock correlations. These correlations indicate long-range lateral and downward cross-stratigraphic net migration. Compaction-driven and elevation head-driven ground-water flows within the basin were numerically modeled using available stratigraphic, structural, and hydrologic data. Calculations based on compaction-driven flow show the possibility of down-stratigraphic migration. Compaction-driven flow, however, cannot explain the amount of lateral transport inferred. Regional ground-water flow due to the uplift of the Pascola arch could explain the long-range lateral migration. Calculations of the effects of advective heat transport by elevation head-driven flow agree with estimates of temperatures made from fluid inclusions in basin mineralization.

Bethke, C.M.; Pruitt, J.D.; Barrows, M.H.

1984-04-01T23:59:59.000Z

300

Fluorescence analysis can identify movable oil in self-sourcing reservoirs  

SciTech Connect (OSTI)

The recent surge of activity involving self-sourcing reservoirs and horizontal drilling recognizes a little tapped niche in the domestic energy mix. Such prolific pays as the Cretaceous Bakken and Austin Chalk have drawn research interest and large amounts of investment capital. Fluorescence analysis can discern movable oil--as opposed to exhausted source rock--in such reservoirs with an inexpensive test. Other potential targets are the Cretaceous Mesaverde in the Piceance basin, Devonian New Albany shale in Kentucky, Devonian Antrim shale in the Michigan basin, and the Cretaceous Niobrara, Mancos, and Pierre formations in Colorado and New Mexico. To insure success in this niche this key question must be answered positively: Is movable oil present in the reservoir? Even if tectonic studies verify a system of open fractures, sonic logs confirm overpressuring in the zone, and resistivity logs document the maturity of the source, the ultimate question remains: Is movable oil in the fractures available to flow to the borehole? The paper explains a technique that will answer these questions.

Calhoun, G.G. [Calhoun (Gerry G.), Midland, TX (United States)

1995-06-05T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


301

Geohydrologic study of the Michigan Basin for the applicability of Jack W. McIntyre`s patented process for simultaneous gas recovery and water disposal in production wells  

SciTech Connect (OSTI)

Geraghty & Miller, Inc. of Midland, Texas conducted a geohydrologic study of the Michigan Basin to evaluate the applicability of Jack McIntyre`s patented process for gas recovery and water disposal in production wells. A review of available publications was conducted to identify, (1) natural gas reservoirs which generate large quantities of gas and water, and (2) underground injection zones for produced water. Research efforts were focused on unconventional natural gas formations. The Antrim Shale is a Devonian gas shale which produces gas and large quantities of water. Total 1992 production from 2,626 wells was 74,209,916 Mcf of gas and 25,795,334 bbl of water. The Middle Devonian Dundee Limestone is a major injection zone for produced water. ``Waterless completion`` wells have been completed in the Antrim Shale for gas recovery and in the Dundee Limestone for water disposal. Jack McIntyre`s patented process has potential application for the recovery of gas from the Antrim Shale and simultaneous injection of produced water into the Dundee Limestone.

Maryn, S.

1994-03-01T23:59:59.000Z

302

Structural evolution and petroleum productivity of the Baltic basin  

SciTech Connect (OSTI)

The Baltic basin is an oval depression located in the western part of the Russian craton; it occupies the eastern Baltic Sea and adjacent onshore areas. The basin contains more than 5,000 m of sedimentary rocks ranging from latest Proterozoic to Tertiary in age. These rocks consist of four tectonostratigraphic sequences deposited during major tectonic episodes of basin evolution. Principal unconformities separate the sequences. The basin is underlain by a rift probably filled with Upper Proterozoic rocks. Vendian and Lower Cambrian rocks (Baikalian sequence) form two northeast-trending depressions. The principal stage of the basin development was during deposition of a thick Middle Cambrian-Lower Devonian (Caledonian) sequence. This stage was terminated by the most intense deformations in the basin history. The Middle Devonian-Carboniferous (Hercynian) and Permian-Tertiary (Kimmerian-Alpine) tectonic and depositional cycles only slightly modified the basin geometry and left intact the main structural framework of underlying rocks. The petroleum productivity of the basin is related to the Caledonian tectonostratigraphic sequence that contains both source rocks and reservoirs. However, maturation of source rocks, migration of oil, and formation of fields took place mostly during deposition of the Hercynian sequence.

Ulmishek, G.F. (Geological Survey, Denver, CO (United States))

1991-08-01T23:59:59.000Z

303

Williston basin oil exploration: Past, present, and future  

SciTech Connect (OSTI)

Past: In 1951, modern oil exploration came to the Williston basin with the discovery of Paleozoic oil on the large Nesson anticline. This was quickly followed by similar discoveries on Cedar Creek and Poplar anticlines. To the north, the Canadians, lacking large structures, concentrated on Paleozoic stratigraphic traps and were highly successful. US explorationists quickly followed, finding similar traps on the basin's northeastern flank and center. The 1960s saw multiple Devonian salt dissolution structures produce on the western flank. To the northwest, shallow Mississippian and deeper Ordovician pays were found on small structural closures. These later were combined with pays in the Devonian and Silurian to give multiple pay potential. In the basin center large buried structures, visible only to seismic, were located. The 1970s revealed an Ordovician subcrop trap on the southeast flank. Centrally, a Jurassic astrobleme with Mississippian oil caused a flurry of leasing and deep drilling. The 1982 collapse of oil prices essentially halted exploration. 1987 saw a revival when horizontal drilling for the Mississippian Bakken fractured shale promised viable economics. Present: Today, emphasis is on Bakken horizontal drilling in the deeper portion of the basin. Next in importance is shallow drilling such as on the northeastern flank. Future: An estimated on billion barrels of new oil awaits discovery in the Williston basin. Additional exploration in already established production trends will find some of this oil. Most of this oil, however, will almost certainly be found by following up the numerous geological leads hinted at by past drilling.

Jennings, A.H.

1991-06-01T23:59:59.000Z

304

A two-dimensional regional basin model of Williston basin hydrocarbon systems  

SciTech Connect (OSTI)

Institut Francais du Petrole`s two-dimensional model, TEMISPACK, is used to discuss the functioning of petroleum systems in the Williston basin along a 330-km-long section, focusing on four regional source intervals: Ordovician Yeoman formation, Lower Devonian Winnipegosis Formation, Upper Devonian-Lower Mississippian Bakken Formation, and Mississippian Lodgepole formation. Thermal history calibration against present temperature and source rock maturity profiles suggests that the Williston basin can be divided into a region of constant heat flow of about 55 mW/m{sup 2} away from the Nesson anticline, and a region of higher heat flow and enhanced thermal maturity in the vicinity of the Nesson anticline. Original kinetic parameters used in the calibration were derived for each of the four source rocks from Rock-Eval yield curves. Bakken overpressures are entirely due to oil generation, not compaction disequilibrium. Very low Bakken vertical permeabilities range from 0.01 to 0.001 and are matched against observed overpressures, whereas Bakken porosities based on the model and confirmed by measurements are inferred to be also unusually low, around 3%.

Burrus, J.; Wolf, S.; Doligez, B. [Institut Francais due Petrole, Rueil-Malmaison (France)] [and others

1996-02-01T23:59:59.000Z

305

Microbial communities in flowback water impoundments from hydraulic fracturing for recovery of shale gas  

SciTech Connect (OSTI)

Hydraulic fracturing for natural gas extraction from shale produces waste brine known as flowback that is impounded at the surface prior to reuse and/or disposal. During impoundment, microbial activity can alter the fate of metals including radionuclides, give rise to odorous compounds, and result in biocorrosion that complicates water and waste management and increases production costs. Here, we describe the microbial ecology at multiple depths of three flowback impoundments from the Marcellus shale that were managed differently. 16S rRNA gene clone libraries revealed that bacterial communities in the untreated and biocide-amended impoundments were depth dependent, diverse, and most similar to species within the taxa [gamma]-proteobacteria, [alpha]-proteobacteria, ?-proteobacteria, Clostridia, Synergistetes, Thermotogae, Spirochetes, and Bacteroidetes. The bacterial community in the pretreated and aerated impoundment was uniform with depth, less diverse, and most similar to known iodide-oxidizing bacteria in the [alpha]-proteobacteria. Archaea were identified only in the untreated and biocide-amended impoundments and were affiliated to the Methanomicrobia class. This is the first study of microbial communities in flowback water impoundments from hydraulic fracturing. The findings expand our knowledge of microbial diversity of an emergent and unexplored environment and may guide the management of flowback impoundments.

Mohan, Arvind Murali; Hartsock, Angela; Hammack, Richard W.; Vidic, Radisav D; Gregory, Kelvin B.

2013-12-01T23:59:59.000Z

306

Hydraulic fracturing in a naturally fractured reservoir  

SciTech Connect (OSTI)

Hydraulic fracturing of wells in naturally fractured reservoirs can differ dramatically from fracturing wells in conventional isotropic reservoirs. Fluid leakoff is the primary difference. In conventional reservoirs, fluid leakoff is controlled by reservoir matrix and fracture fluid parameters. The fluid leakoff rate in naturally fractured reservoirs is typically excessive and completely dominated by the natural fractures. This paper presents several field examples of a fracture stimulation program performed on the naturally fractured Devonia carbonate of West Texas. Qualitative pressure decline analysis and net treating pressure interpretation techniques were utilized to evaluate the existence of natural fractures in the Devonian Formation. Quantitative techniques were utilized to assess the importance of the natural fractures to the fracturing process. This paper demonstrates that bottomhole pressure monitoring of fracture stimulations has benefits over conducting minifrac treatments in naturally fractured reservoirs. Finally, the results of this evaluation were used to redesign fracture treatments to ensure maximum productivity and minimize costs.

Britt, L.K.; Hager, C.J.; Thompson, J.W.

1994-12-31T23:59:59.000Z

307

Research results from the Ashland Exploration, Inc. Ford Motor Company 78 (ed) well, Pike County, Kentucky. Topical report, April 1992-December 1993  

SciTech Connect (OSTI)

This report summarizes the work performed on the Ashland Exploration, Inc. Ford Motor Company 78 (Experimental Development (ED)) Well, in Pike County, KY. The ED well was the third well drilled in a research project conducted by GRI in eastern Kentucky targeting both the Devonian Shales and Berea Sandstone. Both the Shales and Berea were completed and tested in the ED well. The primary objective of the ED well was to apply what was learned from studying the Shalers in COOP 1 (first well drilled) and the Berea in COOP 2 (second well drilled) to both the Shales and the Berea in the ED well. Additionally, the ED well was used to evaluate the impact of different stimulation treatments on Shales production. Research in the ED well brings to a close GRI`s extensive field-based research program in the Appalachian Basin over the last ten years.

Hopkins, C.W.; Frantz, J.H.; Lancaster, D.E.

1995-06-01T23:59:59.000Z

308

Exploration limited since '70s in Libya's Sirte basin  

SciTech Connect (OSTI)

Esso Standard made the first Libyan oil discovery in the western Ghadames basin in 1957. The Atshan-2 well tested oil from Devonian sandstones, and the play was a continuation of the Paleozoic trend found productive in the neighboring Edjeleh region of eastern Algeria. Exploration in the Sirte basin began in earnest in 1958. Within the next 10 years, 16 major oil fields had been discovered, each with recoverable reserves greater than 500 million bbl of oil. Libya currently produces under OPEC quota approximately 1.4 million b/d of oil, with discovered in-place reserves of 130 billion bbl of oil. The paper describes the structural framework, sedimentary basins of Libya, the Sirte basin, petroleum geology, play types, source rocks, generation and migration of hydrocarbons, oil reserves, potential, and acreage availability.

Thomas, D. (Thomas and Associates, Hastings (United Kingdom))

1995-03-13T23:59:59.000Z

309

Deep, water-free gas potential is upside to New Albany shale play  

SciTech Connect (OSTI)

The New Albany shale of the Illinois basin contains major accumulations of Devonian shale gas, comparable both to the Antrim shale of the Michigan basin and the Ohio shale of the Appalachian basin. The size of the resource originally assessed at 61 tcf has recently been increased to between 323 tcf and 528 tcf. According to the 1995 US Geological Survey appraisal, New Albany shale gas represents 52% of the undiscovered oil and gas reserves of the Illinois basin, with another 45% attributed to coalbed methane. New Albany shale gas has been developed episodically for over 140 years, resulting in production from some 40 fields in western Kentucky, 20 fields in southern Indiana, and at least 1 field in southern Illinois. The paper describes two different plays identified by a GRI study and prospective areas.

Hamilton-Smith, T. [Hamilton-Smith LLC, Lexington, KY (United States)

1998-02-16T23:59:59.000Z

310

New Albany shale group of Illinois  

SciTech Connect (OSTI)

The Illinois basin's New Albany shale group consists of nine formations, with the brownish-black laminated shales being the predominant lithology in southeastern Illinois and nearby parts of Kentucky where the group reaches its maximum thickness of 460 ft. A second depositional center lies in west-central Illinois and southeastern Iowa, where the group is about 300 ft thick and the predominant lithology is bioturbated olive-gray to greenish-gray shale. A northeast-trending area of thin strata (mostly interfingering gray and black shales) separates these two depocenters. The distribution and types of lithofacies in the New Albany suggest that the shale was deposited across a shelf-slope-basin transition in a marine, stratified anoxic basin. The record of depositional events in the shale group could serve as a baseline for interpreting the history of tectonically more complex sequences such as the Appalachian basin's Devonian shales.

Cluff, R.M.; Reinbold, M.L.; Lineback, J.A.

1981-01-01T23:59:59.000Z

311

Organic geochemistry and correlation of Paleozoic source rocks and Trenton crude oils, Indiana  

SciTech Connect (OSTI)

Shale samples from four cores of the New Albany and Antrim Shales (Devonian) and from six cores of the Maquoketa Group (Ordovician), representing a broad geographic area of Indiana, have been analyzed for total organic carbon, total sulfur, pyrolysis yield (Rock-Eval), bitumen content, and illite crystallinity data. These data indicate that the New Albany, Antrim, and Maquoketa shales contain a sufficient quantity and quality of organic matter to be good petroleum source rocks. Bitumen ratios, Rock-Eval yields, gas chromatography of saturated hydrocarbons, and illite crystallinity data show that the Maquoketa shales have reached a higher level of thermal maturity than the New Albany and Antrim shales. The level of thermal maturity of the Maquoketa shales suggested a maximum burial depth considerably greater than the present depth.

Guthrie, J. (Indiana Geological Survey, Bloomington (USA))

1989-08-01T23:59:59.000Z

312

Studies of New Albany shale in western Kentucky. Final report  

SciTech Connect (OSTI)

The New Albany (Upper Devonian) Shale in western Kentucky can be zoned by using correlative characteristics distinguishable on wire-line logs. Wells drilled through the shale which were logged by various methods provided a basis for zonation of the subsurface members and units of the Grassy Creek, Sweetland Creek, and Blocher. Structure and isopach maps and cross sections were prepared. The Hannibal Shale and Rockford Limestone were found in limited areas; isopach maps were not made for these members. Samples of cuttings from selected wells were studied in order to identify the contact of the shale with underlying and overlying rock units. A well-site examination of cuttings through the shale section was conducted, and the presence of natural gas was observed in the field. The New Albany Shale has the potential for additional commercially marketable natural gas production. Exploratory drilling is needed to evaluate the reservoir characteristics of the New Albany Shale.

Schwalb, H.R.; Norris, R.L.

1980-02-01T23:59:59.000Z

313

Eastern gas shales bibliography selected annotations: gas, oil, uranium, etc. Citations in bituminous shales worldwide  

SciTech Connect (OSTI)

This bibliography contains 2702 citations, most of which are annotated. They are arranged by author in numerical order with a geographical index following the listing. The work is international in scope and covers the early geological literature, continuing through 1979 with a few 1980 citations in Addendum II. Addendum I contains a listing of the reports, well logs and symposiums of the Unconventional Gas Recovery Program (UGR) through August 1979. There is an author-subject index for these publications following the listing. The second part of Addendum I is a listing of the UGR maps which also has a subject-author index following the map listing. Addendum II includes several important new titles on the Devonian shale as well as a few older citations which were not found until after the bibliography had been numbered and essentially completed. A geographic index for these citations follows this listing.

Hall, V.S. (comp.)

1980-06-01T23:59:59.000Z

314

Underground gas storage in New York State: A historical perspective  

SciTech Connect (OSTI)

New York State has a long history of underground gas storage activity that began with conversion of the Zoar gas field into a storage reservoir in 1916, the first in the United States. By 1961 another fourteen storage fields were developed and seven more were added between 1970 and 1991. All twenty-two operating storage reservoirs of New York were converted from depleted gas fields and are of low-deliverability, base-load type. Nineteen of these are in sandstone reservoirs of the Lower Silurian Medina Group and the Lower Devonian Oriskany Formation and three in limestone reservoirs are located in the gas producing areas of southwestern New York and are linked to the major interstate transmission lines. Recent developments in underground gas storage in New York involve mainly carbonate-reef and bedded salt-cavern storage facilities, one in Stuben County and the other in Cayuga County, are expected to begin operation by the 1996-1997 heating season.

Friedman, G.M.; Sarwar, G.; Bass, J.P. [Brooklyn College of the City Univ., Troy, NY (United States)] [and others

1995-09-01T23:59:59.000Z

315

Soil chemical properties of the residuum of Callaway County, Missouri  

SciTech Connect (OSTI)

Soil samples of Callaway County, Missouri, were analyzed for soil pH, clay mineralogy, free iron and manganese oxides, total organic carbon content (TOC), and cation exchange capacity (CEC). The soil samples represent Ordovician, Devonian, Mississippian and Pennsylvanian residuum. In addition, alluvium, loess, colluvium and glacial till samples were analyzed. The clay minerals consist of kaolinite, illite, smectite and illite-smectite mixed layers, iron and manganese oxide content ranges from 0.137 to 2.87% and 0.003 to 0.082% respectively, while TOC values range from 0.03 to 3.00%. The CEC values show a wide range from 5 to 89 milliequivalent/100 grams. The influence of the different soil constituents on the adsorption capacity of the soils is evaluated.

Biggs, T.C. (REACT Environmental Engineers, St. Louis, MO (United States)); Bolter, E. (Univ. of Missouri, Rolla, MO (United States). Dept. of Geology and Geophysics)

1993-03-01T23:59:59.000Z

316

A lodgepole play in North Dakota  

SciTech Connect (OSTI)

The Lodgepole formation has been the major producing horizon in the Manitoba portion of the Williston basin, but it has not been a target in North Dakota except for limited interest along the northeast flank in early exploration. Completion of the Conoco-Dickenson State well 74, located in SW NW, Sec. 32, T140N, R96W, on February 3, 1993, for an IP of 2,045 bbl of oil, 164 mcf gas/day from the Lodgepole formation startled explorationists and requires a reexamination of Lodgepole stratigraphic concepts. Lineback and Davidson (1982) proposed that the Illinois and Williston basins were sediment-starved basins during the Late Devonian through the middle Mississippian. Cross sections of the Lodgepole formation from basin margins to the central basin area are consistent with that model. Facies changes within the Lodgepole formation indicate that the recent discovery is in clinoform carbonates basinward from persistent argillaceous beds.

Carlson, C.G. (NDIC, Bismark, ND (United States))

1993-08-01T23:59:59.000Z

317

Correlation cross sections along the international border  

SciTech Connect (OSTI)

The Manitoba-North Dakota (Canada-US) stratigraphic correlation project is a joint study between the Petroleum Branch of Manitoba Energy and Mines and the North Dakota Geological Survey. It is an attempt to correlate the differing stratigraphic terminologies established in the two jurisdictions by providing a reference cross section across the international boundary. The study involves the subsurface correlation of logs of the Paleozoic and Mesozoic sequences in the Manitoba and North Dakota portions of the Williston basin. The Paleozoic and Mesozoic sequences are subdivided for presentation into the following stratigraphic intervals: (a) Cambrian-Ordovician-Silurian, (b) Devonian, (c) Mississippian, (d) Jurassic, and (e) Cretaceous. Wireline logs show the actual stratigraphic correlations. A nomenclature chart is also presented from each sequence. In addition, the sections include a generalized description of lithologies, thicknesses, environments of deposition, and petroleum potential for each geographic area.

Martiniuk, C.D. (Manitoba Energy and Mines, Winnipeg (Canada)); Le Fever, J.A.; Anderson, S.B. (North Dakota Geological Survey, Grand Forks (United States))

1991-06-01T23:59:59.000Z

318

Economic appraisal of oil potential of Williston basin  

SciTech Connect (OSTI)

An economic appraisal was made of the potential of more than 80 producing fields in the Williston basin of Montana, North Dakota, and South Dakota. The major oil producing formations investigated were in the Mississippian, Devonian, Silurian and Ordovician. Data for the study came from field production and drilling statistics. An extrapolated oil production decline curve for a theoretical average producing well first was made for each field. The value of the total extrapolated amount of producible oil for the average well was then calculated, discounted for royalty, taxes, etc., and divided by the estimated cost for a completed producing well. This gave an estimate of the return per dollar invested. No considerations were given for exploration and land acquisition costs. The estimated return per dollar values, after posting on Williston basin geologic maps, show relative economic comparisons of producing formations and where within the basin the best economic returns can be expected.

Jennings, A.H.

1983-08-01T23:59:59.000Z

319

Stimulation rationale for shale gas wells: a state-of-the-art report  

SciTech Connect (OSTI)

Despite the large quantities of gas contained in the Devonian Shales, only a small percentage can be produced commercially by current production methods. This limited production derives both from the unique reservoir properties of the Devonian Shales and the lack of stimulation technologies specifically designed for a shale reservoir. Since October 1978 Science Applications, Inc. has been conducting a review and evaluation of various shale well stimulation techniques with the objective of defining a rationale for selecting certain treatments given certain reservoir conditions. Although this review and evaluation is ongoing and much more data will be required before a definitive rationale can be presented, the studies to date do allow for many preliminary observations and recommendations. For the hydraulic type treatments the use of low-residual-fluid treatments is highly recommended. The excellent shale well production which is frequently observed with only moderate wellbore enlargement treatments indicates that attempts to extend fractures to greater distances with massive hydraulic treatments are not warranted. Immediate research efforts should be concentrated upon limiting production damage by fracturing fluids retained in the formation, and upon improving proppant transport and placement so as to maximize fracture conductivity. Recent laboratory, numerical modeling and field studies all indicate that the gas fracturing effects of explosive/propellant type treatments are the predominate production enhancement mechanism and that these effects can be controlled and optimized with properly designed charges. Future research efforts should be focused upon the understanding, prediction and control of wellbore fracturing with tailored-pulse-loading charges. 36 references, 7 figures, 2 tables.

Young, C.; Barbour, T.; Blanton, T.L.

1980-12-01T23:59:59.000Z

320

Similarities in the Paleozoic successions of north Africa and Arabia and implications for petroleum exploration  

SciTech Connect (OSTI)

From field studies in southwest Libya and northwest Saudi Arabia, the facies of the Paleozoic succession of the north African/Arabian stable cratonic margin of Gondwanaland are interpreted as fluvial, estuarine, deltaic, shallow marine, and glacial deposits. The facies of the Saq and Tabuk Formations of Saudi Arabia bear witness to a sedimentary history that is very similar to that of north Africa, the Saq Formation (Cambrian-Arenig) being equivalent to the Hassaouna Formation of Libya and the Tabuk Formation being subdivided and correlated using well-dated shale members to the following formations: Haouaz (Llanvirn-Llandeilo), Melez-Chograne (Caradoc), Memouniat (Ashgill), Tanezzuft/Acacus (Llandovery-Ludlow), and Tadrart (Gedinnian -Emsian). The Cambrian-Ordovician succession comprises Nubian-type fluvial and estuarine sandstones which pass up to regressive deltaic/shallow marine sequences overlain by Upper Ordovician glacial deposits that lie in deeply incised paleovalleys recorded from Saudi Arabia and north Africa. The Silurian succession comprises the deposits of a postglacial marine transgression of vast lateral extent and a subsequent regression, the sandstones of which are markedly diachronous. The Lower Devonian succession comprises fining-upward retrogradational deltaic (transgressive) sequences of Nubian-type sandstones (fluvial to shallow marine) which form widespread blanket sandstone bodies. The prospectivity of these strata is well known from Algeria in the west to Jordan in the east, the Llandoverian oil-prone source rocks providing the key to Cambrian-Ordovician and Lower Devonian plays. The significance of underlying paleovalley-fill fluvioglacial sandstones as linear reservoir targets has yet to be fully appreciated.

Clark-Lowes, D.D. (Scott Pickford and Associates Ltd., Surrey (England))

1988-08-01T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


321

RISK REDUCTION WITH A FUZZY EXPERT EXPLORATION TOOL  

SciTech Connect (OSTI)

Incomplete or sparse information on types of data such as geologic or formation characteristics introduces a high level of risk for oil exploration and development projects. ''Expert'' systems developed and used in several disciplines and industries have demonstrated beneficial results. A state-of-the-art exploration ''expert'' tool, relying on a computerized database and computer maps generated by neural networks, is being developed through the use of ''fuzzy'' logic, a relatively new mathematical treatment of imprecise or non-explicit parameters and values. Oil prospecting risk can be reduced with the use of a properly developed and validated ''Fuzzy Expert Exploration (FEE) Tool.'' This FEE Tool can be beneficial in many regions of the U.S. by enabling risk reduction in oil and gas prospecting as well as decreased prospecting and development costs. In the 1998-1999 oil industry environment, many smaller exploration companies lacked the resources of a pool of expert exploration personnel. Downsizing, low oil prices, and scarcity of exploration funds have also affected larger companies, and will, with time, affect the end users of oil industry products in the U.S. as reserves are depleted. The FEE Tool will benefit a diverse group in the U.S., leading to a more efficient use of scarce funds, and possibly decreasing dependence on foreign oil and lower product prices for consumers. This fifth annual (and tenth of 12 semi-annual reports) contains a summary of progress to date, problems encountered, plans for the next year, and an assessment of the prospects for future progress. The emphasis during the March 2003 through March 2004 period was directed toward completion of the Brushy Canyon FEE Tool and to Silurian-Devonian geology, and development of rules for the Devonian fuzzy system, and on-line software.

Robert Balch

2004-04-08T23:59:59.000Z

322

The Keg River/Winnipegosis petroleum system - Source to trap (part 2)  

SciTech Connect (OSTI)

The Keg River/Winnipegosis Formation is a heterogeneous hydrocarbon system composed of three oil families based upon gas chromatography of extracts from nine potential source rocks, six oil stained cores, and oils from fourteen Keg River/Winnipegosis fields. Family 1 - The 'pinnacle' play oils (North Alberta, South Saskatchewan, and North Dakota), together with Virago field (Southeast Alberta), comprise a locally sourced (upper Keg River/lower Muskeg/Ratner) family that exhibits a broad maturity range heavily dependent upon present burial depths and geothermal gradients. Family 2 - Oils from Utikima Lake, Peerless, Panny, and Senex fields in Alberta are a homogeneous, migrated oil sourced from the Duvernay Formation (upper Devonian). Family 3 - Oils from Temple field (North Dakota) and oil-stained carbonate cores of west-central Saskatchewan are of unknown source (possibly mixed Ordovician and Devonian or Mississippian). Long-distance (> 200 mi or > 320 km) oil migration routes through the thermally immature Keg River carbonates of Northeast Alberta were tracked by epi-fluorescence (E-F) study of 200 thin sections. Drill stem test (DST) recoveries and E-F oil shows demonstrate that oil migration extended northeast of the Senex area to the Keg River shelf margin. Oil migration along the shelf margin was southeast, oblique to regional structural dip. E-F shows in shelf margin strata continue southeast to the Cold Lake Weapon Range where a pre-Cretaceous dissolution event removed the overlying Muskeg halite seal. Porous carbonates of the Keg River shelf margin were possibly a migration route for oils sourcing the Cretaceous Athabasca oil sands overlying this dissolution area.

Kirkby, K.C. (Union Pacific Resources, Madison, WI (United States)); Tinker, S.W. (Marathon Oil Co., Littleton, CO (United States))

1991-03-01T23:59:59.000Z

323

Horizontal drilling the Bakken Formation, Williston basin: A new approach  

SciTech Connect (OSTI)

Horizontal drilling is an attractive new approach to exploration and development of the Mississippian/Devonian Bakken Formation in the southwestern part of North Dakota. This drilling technique increases the probability of success, the profit potential, the effective drainage area maximizing recoverable reserves, and the productivity by encountering more natural occurring fractures. The target formation, the Mississippian/Devonian Bakken, consists of three members in an overlapping relationship, a lower organic-rich black shale, a middle siltstone/limestone, and an upper organic-rich black shale. It attains a maximum thickness of 145 ft and thins to a feather edge along its depositional limit. Considered to be a major source rock for the Williston basin, the Bakken is usually overpressured where productive. Overpressuring is attributed to intense hydrocarbon generation. Reservoir properties are poor with core fluid porosities being generally 5% or less and permeabilities ranging from 0.1 to 0.2 md. The presence of natural fractures in the shale are necessary for production. Two types of fractures are associated with Bakken reservoirs: large vertical fractures (of tectonic origin) and microfractures (probably related to hydrocarbon generation). An economic comparison between horizontal and vertical wells show that well completion costs are approximately two times higher (average costs; $1,500,000 for a horizontal to $850,000 for a vertical) with average payout for horizontal wells projected to occur in half the time (1.5 yr instead of 3.4 yr). Projected production and reserves are considered to be 2 to 4 times greater from a horizontal well.

Lefever, J.A. (North Dakota Geological Survey, Grand Forks (USA))

1990-05-01T23:59:59.000Z

324

Characterization of the Wymark CO2 Reservoir: A Natural Analog to Long-Term CO2 Storage at Weyburn  

SciTech Connect (OSTI)

Natural accumulations of CO{sub 2} occur in the Duperow and other Devonian strata on the western flank of the Williston Basin in lithologies very similar to those into which anthropogenic CO{sub 2} is being injected as part of an EOR program in the Weyburn-Midale pool. Previous workers have established the stratgraphic and petrographic similarities between the Duperow and Midale beds (Lake and Whittaker, 2004 and 2006). As the CO{sub 2} accumulations in the Devonian strata may be as old as 50 Ma, this similarity provides confidence in the efficacy of long-term geologic sequestration of CO{sub 2} in the Midale-Weyburn pool. Here we attempt to extend this comparison with whole rock and mineral chemistry using the same sample suite used by Lake and Whittaker. We provide XRD, XRF, and electron microprobe analysis of major constituent minerals along with extensive backscattered electron and x-ray imaging to identify trace phases and silicate minerals. LPNORM analysis is used to quantify modal concentrations of minerals species. Samples from depth intervals where CO{sub 2} has been observed are compared to those where CO{sub 2} was absent, with no systematic differences in mineral composition observed. Gas accumulation can be correlated with sample porosity. In particular gas-bearing samples from the Eastend region are more porous than the overlying gas-free samples. Silicate minerals are rare in the Duperow carbonates, never exceeding 3 wt%. As such, mineral trapping is precluded in these lithologies. The geochemical data presented here will be used for comparison with a similar geochemical-mineralogical study of the Midale (Durocher et al., 2003) in a subsequent report.

Ryerson, F; Johnson, J

2010-11-22T23:59:59.000Z

325

Phase I (Year 1) Summary of Research--Establishing the Relationship between Fracture-Related Dolomite and Primary Rock Fabric on the Distribution of Reservoirs in the Michigan Basin  

SciTech Connect (OSTI)

This topical report covers the first 12 months of the subject 3-year grant, evaluating the relationship between fracture-related dolomite and dolomite constrained by primary rock fabric in the 3 most prolific reservoir intervals in the Michigan Basin (Ordovician Trenton-Black River Formations; Silurian Niagara Group; and the Devonian Dundee Formation). Phase I tasks, including Developing a Reservoir Catalog for selected dolomite reservoirs in the Michigan Basin, Characterization of Dolomite Reservoirs in Representative Fields and Technology Transfer have all been initiated and progress is consistent with our original scheduling. The development of a reservoir catalog for the 3 subject formations in the Michigan Basin has been a primary focus of our efforts during Phase I. As part of this effort, we currently have scanned some 13,000 wireline logs, and compiled in excess of 940 key references and 275 reprints that cover reservoir aspects of the 3 intervals in the Michigan Basin. A summary evaluation of the data in these publications is currently ongoing, with the Silurian Niagara Group being handled as a first priority. In addition, full production and reservoir parameter data bases obtained from available data sources have been developed for the 3 intervals in Excel and Microsoft Access data bases. We currently have an excess of 25 million cells of data for wells in the Basin. All Task 2 objectives are on time and on target for Phase I per our original proposal. Our mapping efforts to date, which have focused in large part on the Devonian Dundee Formation, have important implications for both new exploration plays and improved enhanced recovery methods in the Dundee ''play'' in Michigan--i.e. the interpreted fracture-related dolomitization control on the distribution of hydrocarbon reservoirs. In an exploration context, high-resolution structure mapping using quality-controlled well data should provide leads to convergence zones of fault/fracture trends that are not necessarily related to structural elevation. Further work in Phase II will be focused on delineating the relative contribution to fracture-only dolomitization to that which occurs in conjunction with primary facies and/or sequence stratigraphic framework.

G. Michael Grammer

2005-11-09T23:59:59.000Z

326

Oil and gas basins in the former Soviet Union  

SciTech Connect (OSTI)

The Pripyat basin is a Late Devonian rift characterized by a typical fault-block structure. Two synrift salt formations separate the Devonian stratigraphic succession into the subsalt, intersalt, and postsalt sections. Oil is produced from carbonate reservoirs of the subsalt and intersalt sections. Traps are controlled by crests of tilted fault blocks. We analyzed 276 shale and carbonate-rock samples and 21 oils to determine oil-source bed relationships in the basin. Maturities of the oils are from very immature, heavy (9[degrees] API), to very mature, light (42[degrees] API). All fields are in a narrow band on the north side of the basin, and only shows of immature, heavy oil have been obtained from the rest of the basin. Three genetic oil types are identified. Oil type A has high pristane/phytane ratios (>1.0), high amounts of C[sub 29] 18[alpha] (H) trisnorneohopane, and [delta]13C of hydrocarbons in the range of -31 to -27%. Oil types B and C contain very high amounts of gammacerane, which suggests that the oils were derived from carbonate-evaporite source facies. Type B oils are isotopically similar to type A, whereas type C oils are isotopically light (about -33%). Organic carbon content is as much as 5%, and kerogen types range from I to IV. Our data indicate that rocks within the intersalt carbonate formation are the source of the type B oils of low maturity. Thermally mature rocks that might be the source for the mature oils have not been found. Such rocks may occur in depressions adjacent to tilted fault blocks. Higher levels of thermal maturity on the north part of the basin in the vicinity of the most mature oils may be related to higher heat flow during and soon after rifting or to a suspected recently formed magmatic body in the crust below the northern zone. Present-day high temperatures in parts of the northern zone may support the latter alternative.

Clayton, J. (Geological Survey, Denver, CO (United States))

1993-09-01T23:59:59.000Z

327

Comprehensive Lifecycle Planning and Management System For Addressing Water Issues Associated With Shale Gas Development In New York, Pennsylvania, And West Virginia  

SciTech Connect (OSTI)

The objective of this project is to develop a modeling system to allow operators and regulators to plan all aspects of water management activities associated with shale gas development in the target project area of New York, Pennsylvania, and West Virginia (??target area?), including water supply, transport, storage, use, recycling, and disposal and which can be used for planning, managing, forecasting, permit tracking, and compliance monitoring. The proposed project is a breakthrough approach to represent the entire shale gas water lifecycle in one comprehensive system with the capability to analyze impacts and options for operational efficiency and regulatory tracking and compliance, and to plan for future water use and disposition. It will address all of the major water-related issues of concern associated with shale gas development in the target area, including water withdrawal, transport, storage, use, treatment, recycling, and disposal. It will analyze the costs, water use, and wastes associated with the available options, and incorporate constraints presented by permit requirements, agreements, local and state regulations, equipment and material availability, etc. By using the system to examine the water lifecycle from withdrawals through disposal, users will be able to perform scenario analysis to answer "what if" questions for various situations. The system will include regulatory requirements of the appropriate state and regional agencies and facilitate reporting and permit applications and tracking. These features will allow operators to plan for more cost effective resource production. Regulators will be able to analyze impacts of development over an entire area. Regulators can then make informed decisions about the protections and practices that should be required as development proceeds. This modeling system will have myriad benefits for industry, government, and the public. For industry, it will allow planning all water management operations for a project or an area as one entity to optimize water use and minimize costs subject to regulatory and other constraints. It will facilitate analysis of options and tradeoffs, and will also simplify permitting and reporting to regulatory agencies. The system will help regulators study cumulative impacts of development, conserve water resources, and manage disposal options across a region. It will also allow them to track permits and monitor compliance. The public will benefit from water conservation, improved environmental performance as better system wide decisions are made, and greater supply of natural gas, with attendant lower prices, as costs are reduced and development is assisted through better planning and scheduling. Altogether, better economics and fewer barriers will facilitate recovery of the more than 300 trillion cubic feet of estimated recoverable natural gas resource in the Marcellus Shale in a manner that protects the environment.

J. Daniel Arthur

2012-03-31T23:59:59.000Z

328

Shale-Gas Experience as an Analog for Potential Wellbore Integrity Issues in CO2 Sequestration  

SciTech Connect (OSTI)

Shale-gas development in Pennsylvania since 2003 has resulted in about 19 documented cases of methane migration from the deep subsurface (7,0000) to drinking water aquifers, soils, domestic water wells, and buildings, including one explosion. In all documented cases, the methane leakage was due to inadequate wellbore integrity, possibly aggravated by hydrofracking. The leakage of methane is instructive on the potential for CO{sub 2} leakage from sequestration operations. Although there are important differences between the two systems, both involve migrating, buoyant gas with wells being a primary leakage pathway. The shale-gas experience demonstrates that gas migration from faulty wells can be rapid and can have significant impacts on water quality and human health and safety. Approximately 1.4% of the 2,200 wells drilled into Pennsylvania's Marcellus Formation for shale gas have been implicated in methane leakage. These have resulted in damage to over 30 domestic water supplies and have required significant remediation via well repair and homeowner compensation. The majority of the wellbore integrity problems are a result of over-pressurization of the wells, meaning that high-pressure gas has migrated into an improperly protected wellbore annulus. The pressurized gas leaks from the wellbore into the shallow subsurface, contaminating drinking water or entering structures. The effects are localized to a few thousands of feet to perhaps two-three miles. The degree of mixing between the drinking water and methane is sufficient that significant chemical impacts are created in terms of elevated Fe and Mn and the formation of black precipitates (metal sulfides) as well as effervescing in tap water. Thus it appears likely that leaking CO{sub 2} could also result in deteriorated water quality by a similar mixing process. The problems in Pennsylvania highlight the critical importance of obtaining background data on water quality as well as on problems associated with previous (legacy) oil and gas operations. The great majority of the leakage issues in Pennsylvania are due to improperly abandoned wells, however in the media there is no clear distinction between past and present problems. In any case, significant analytical work is required to attribute differing sources of methane (or CO{sub 2} in the case of sequestration). In Pennsylvania, a relatively lax regulatory environment appears to have contributed to the problem with inadequate oversight of well design and testing to ensure well integrity. New rules were adopted at the end of 2010, and it will be interesting to observe whether methane leakage problems are significantly reduced.

Carey, James W. [Los Alamos National Laboratory; Simpson, Wendy S. [Los Alamos National Laboratory; Ziock, Hans-Joachim [Los Alamos National Laboratory

2011-01-01T23:59:59.000Z

329

Pressurized fluidized-bed hydroretorting of Eastern oil shales. Progress report, July--September 1988  

SciTech Connect (OSTI)

The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the 3-year program, is to perform the research necessary to develop the pressurized fluidized-bed hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The program is divided into the following eight tasks: Task 1, PFH Scoping Studies; Task 2, PFH Optimization Tests; Task 3, Testing of Process Improvement Concepts; Task 4, Beneficiation Research; Task 5, Operation of PFH on Beneficiated Shale; Task 6, Environmental Data and Mitigation Analyses; Task 7, Sample Procurement, Preparation, and Characterization; Task 8, Project Management and Reporting. In order to accomplish all the program objectives, the Institute of Gas Technology, the prime contractor, is working with six other institutions; the University of Alabama/Mineral Resources Institute, Illinois Institute of Technology, the University of Michigan, Ohio State University, Tennessee Technological University and the University of Pittsburgh. This report presents the work performed during the fourth program quarter from July 1 through September 30, 1988.

Punwani, D.V.; Lau, F.S.; Knowlton, T.M.; Akin, C.; Roberts, M.J.; Findlay, J.G.; Mensinger, M.C.; Chang, I.H.; Xiong, T.Y.

1988-12-01T23:59:59.000Z

330

Br-Cl-Na systematics in Illinois basin fluids: Constraints on fluid origin and evolution  

SciTech Connect (OSTI)

The authors present here bromide, chloride, and sodium data for fluids from reservoirs of Ordovician through Pennsylvania age in the Illinois basic which suggest that remnant marine fluids contribute significantly to fluid Cl budgets. Cl/Br and NaBr ratios for Ordovician through Devonian formation fluids are relatively uniform and near those for seawater, despite greater than a factor of ten range in Cl concentration. In contrast, fluids from Mississippian and Pennsylvanian reservoirs, separated from older reservoirs by the New Albany Shale Group, have more variable fluid Cl/Br and Na/Br ratios, most of which are significantly greater then those of seawater. The 1:1 stoichiometry of Cl and Na increases for Mississippian and Pennsylvanian formation fluids is consistent with halite dissolution. Nevertheless, Br systematics and mass-balance considerations indicate that he overall Cl budget of Illinois basin formation fluids appears to be more significantly influenced by the contribution from subaerially evaporated seawater than by halite dissolution.

Walter, L.M.; Huston, T.J. (Washington Univ., St. Louis, Missouri (USA)); Stueber, A.M. (Southern Illinois Univ., Edwardsville (USA))

1990-04-01T23:59:59.000Z

331

Pressurized Fluidized-Bed Hydroretorting of Eastern Oil Shales. Progress report, July--September 1989  

SciTech Connect (OSTI)

The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the 3-year program, initiated in October 1987 is to perform the research necessary to develop the pressurized fluidized-bed hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The program is divided into the following eight tasks: Task 1, PFH Scoping Studies; Task 2, PFH Optimization Tests; Task 3, Testing of Process Improvement Concepts; Task 4, Beneficiation Research; Task 5, Operation of PFH on Beneficiated Shale; Task 6, Environmental Data and Mitigation Analyses; Task 7, Sample Procurement, Preparation, and Characterization; Task 8, Project Management and Reporting. In order to accomplish all the program objectives, the Institute of Gas Technology, the prime contractor, is working with seven other institutions; the University of Alabama/Mineral Resources Institute, Illinois Institute of Technology, the University of Michigan, the University of Nevada, Ohio State University, Tennessee Technological University and the University of Pittsburgh. This report presents the work performed during the eighth program quarter from July 1 through September 30, 1989.

Punwani, D.V.; Lau, F.S.; Knowlton, T.M. [and others

1989-12-01T23:59:59.000Z

332

Preliminary assessment of hydrocarbon potential in southern Illinois  

SciTech Connect (OSTI)

Hydrocarbon exploration has been sparse south of the Cottage Grove fault system in southern Illinois. Over 240,000 ac in this area are within the Shawnee National Forest (SNF). Upcoming review of mineral exploration policy on SNF land and a recent amendment to the Mineral Leasing Act (1987) will result in release of portions of the SNF for competitive and potentially noncompetitive bidding for mineral exploration tracts in the near future. Preliminary assessment of hydrocarbon potential has been carried out in southern Illinois. Numerous oil shows occur in Paleozoic strata south of the Cottage Grove fault system, which, at present, describes the southern boundary of most oil production in Illinois. Only Mitchellsville oil field in southern Saline County lies south of the Cottage Grove fault system. The Upper Devonian New Albany Shale, though to be the primary source rock for Illinois basin hydrocarbons, underlies most of the area. Older potential source rocks may be present. Depositional trends of prolific oil-productive Mississippian strata in Illinois continue southward through the area. Few drill holes have tested strata older than Mississippian in the area. Complex faulting in the Rough Creek-Shawneetown fault system may have improved the potential for hydrocarbon emplacement and entrapment in this region. Preliminary assessment of hydrocarbon potential indicates that this wildcat region deserves further tests.

Crockett, J.E.; Oltz, D.F. (Illinois State Geological Survey, Champaign (USA))

1989-08-01T23:59:59.000Z

333

Pressurized Fluidized-Bed Hydroretorting of Eastern Oil Shales. Progress report, October--December 1988  

SciTech Connect (OSTI)

The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the 3-year program, initiated in October 1987 is to perform the research necessary to develop the pressurized fluidized-bed hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The program is divided into the following eight tasks: Task 1, PFH Scoping Studies; Task 2, PFH Optimization Tests; Task 3, Testing of Process Improvement Concepts; Task 4, Beneficiation Research; Task 5, Operation of PFH on Beneficiated Shale; Task 6, Environmental Data and Mitigation Analyses; Task 7, Sample Procurement, Preparation, and Characterization; Task 8, Project Management and Reporting. In order to accomplish all the program objectives, the Institute of Gas Technology, the prime contractor, is working with seven other institutions; the University of Alabama/Mineral Resources Institute, Illinois Institute of Technology, the University of Michigan, the University of Nevada, Ohio State University, Tennessee Technological University and the University of Pittsburgh. This report presents the work performed during the fifth program quarter from October 1 through December 31, 1988.

Punwani, D.V.; Lau, F.S.; Knowlton, T.M. [and others

1989-02-01T23:59:59.000Z

334

Strontium isotopic study of subsurface brines from Illinois basin  

SciTech Connect (OSTI)

The abundance of the radiogenic isotope /sup 87/Sr in a subsurface brine can be used as a tracer of brine origin, evolution, and diagenetic effects. The authors have determined the /sup 87/Sr//sup 86/Sr ratios of over 60 oil-field waters from the Illinois basin, where brine origin is perplexing because of the absence of any significant evaporite strata. Initially, they analyzed brines from 15 petroleum-producing sandstone and carbonate units; waters from Ordovician, Silurian, Devonian, and Mississippian strata have /sup 87/Sr//sup 86/Sr ratios in the range 0.7079-0.7108. All but those from the Ste. Genevieve Limestone (middle Mississippian) are more radiogenic in /sup 87/Sr//sup 86/Sr than seawater values for this interval of geologic time. The detrital source of the more radiogenic /sup 87/Sr may be the New Albany Shale group, considered to be a major petroleum source rock in the basin. The /sup 87/Sr//sup 86/Sr ratios of Ste. Genevieve brines apparently evolved without a contribution from fluid-shale interaction.

hetherington, E.A.; Stueber, A.M.; Pushkar, P.

1986-05-01T23:59:59.000Z

335

Evaluating Berea Sandstone reservoirs in eastern Ashland County, Ohio  

SciTech Connect (OSTI)

The Berea Sandstone is a principal oil and gas reservoir in eastern Ashland County. It is stratigraphically situated above the red and gray Bedford shales and below the black Sunbury shale member of the Cuyahoga Formation, all of which are Late Devonian or Early Mississippian in age. In the study area, the Berea Sandstone is found at depths between 400 and 800 ft. It outcrops in an arcuate band to the north and west of the county. Geophysical logs indicate the reservoir capacity of the Berea is between 8 and 22%, with an average porosity of 15%. Generally, the Berea is a loosely cemented, gray to buff quartzose sandstone with few accessory minerals. The cement may be calcite, silica, or minor ferruginous materials. The reservoir geometry in eastern Ashland County is peculiar because these sands thin and thicken within relatively short distances. The long-standing explanation for this phenomenon is that these sands were deposited in incised river channels that had downcut through the Bedford shales as a result of isolated uplift in north-central Ohio. Recent subsurface mapping in this area shows that the continuity of these channels may be challenged. Also, well-ticket data indicate that red shale occurs above the Berea sands. This occurrence and the soft-sediment deformation between the Bedford Shale and Berea Sandstone indicate that these units were deposited contemporaneously rather than as two separate events.

Hillebrand, L.B.; Coogan, A.H.

1986-08-01T23:59:59.000Z

336

Evaluation of the Berea sandstone formation in eastern Pike County, Kentucky  

SciTech Connect (OSTI)

The Gas Research Institute (GRI) has been sponsoring a cooperative well program with Ashland Exploration, Inc., (AEI) during the past two years targeting the Devonian Shale and Berea sandstone formations in Pike County of eastern Kentucky. Operators typically complete both the shales and Berea in one well bore in this area. This presentation summarizes the research results of the Berea cooperative well, the COOP 2 (Ashland FMC 80). The specific objectives of the Berea evaluation in the COOP 2 were to develop an integrated reservoir description for stimulation design and predicting long-term well performance, identify geologic production controls, determine the in-situ stress profile, and develop Berea log interpretation models for gas porosity and stress. To satisfy these objectives, data were collected and analyzed from 146 ft of whole core, open-hole geophysical logs, including formation microscanner and digital sonic, in-situ stress measurements, and prefracture production and pressure transient tests. In addition, data from a minifracture, a fracture stimulation treatment, and postfracture performance tests were analyzed. The authors determined the integrated reservoir/hydraulic fracture descriptions from analyzing the data collected in the open- and cased-hole, in addition to the log interpretation models developed to accurately predict gas porosity and stress profiles. Results can be applied by operators to better understand the Berea reservoir in the study area, predict well performance, and design completion procedures and stimulation treatments. The methodology can also be applied to other tight-gas sand formations.

Frantz, J.H. Jr. (S.A. Holditch Associates, Inc., Pittsburgh, PA (United States)); Luffel, D. (ResTech Houston, Inc., Houston, TX (United States)); Kubik, W. (K A Energy Consultants, Tulsa, OK (United States))

1993-08-01T23:59:59.000Z

337

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

SciTech Connect (OSTI)

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.

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

1987-09-01T23:59:59.000Z

338

Geology, Murzuk oil development could boost S. W. Libya prospects  

SciTech Connect (OSTI)

With the recent involvement of Repsol, Total, and OMV in developing the 2 billion bbl oil-in-place Murzuk field complex, an infrastructure will be finally constructed in western Libya which will act as a precursor to more exploration activity and development projects in the Murzuk and Ghadames basins. Murzuk, an intra-cratonic sag basin, is a huge ladle-shaped structural basin covering more than 400,000 sq km and extending beyond the borders of southern Libya. The structure of the area is quite simple. The sub-horizontal or gently dipping strata are faulted and the faults are most frequently parallel to the anticlinal axis. Tectonic movements affected the basin to a greater or lesser degree from early Paleozoic (Caledonian) to post-Eocene (Alpine) times. The paper describes the exploration history; stratigraphy; the Ordovician, Silurian and Devonian, and Carboniferous reservoirs; source rocks; oil gravity and gas content; hydrogeologic constraints; aquifer influence on hydrocarbon accumulation; geologic structures; Murzuk field development; and acreage availability.

Thomas, D. (Thomas and Associates, Hastings (United Kingdom))

1995-03-06T23:59:59.000Z

339

Cyrenaican platform: structure, stratigraphy, and exploration play concepts  

SciTech Connect (OSTI)

The structural and stratigraphic history of the Cyrenaican platform of eastern Libya is closely related to that of both the Sirte basin and the Western Desert of Egypt. At the end of the Paleozoic Hercynian orogeny, this area comprised the eastern end of the Sirte arch, the precursor of the Sirte basin. When the arch collapsed in the mid-Cretaceous, initiating the Sirte basin, the Cyrenaican area remained relatively high. A northwest-southeast trending high, the Gabboub arch, formed on the platform in the early Mesozoic, dividing the region into three areas: the high itself, a deep on the southwestern flank related to the Sirte basin, and a deep on the northeastern flank, which plunges into the offshore and appears to relate to the downwarped offshore area of the Western Desert of Egypt. Sediments of every age, except Triassic, are found in Cyrenaica. Paleozoic sediments are composed primarily of quartzitic sandstones and shales with lesser amounts of limestone, dolomites, and anhydrites. Mesozoic sediments are a mixture of clastics and carbonates. Cenozoic sediments are predominantly limestones, dolomites, and anhydrites with some sandstones and shales. Environments of deposition range from continental to deep marine. The Cyrenaican area has not been heavily explored and, until recently, no commercial hydrocarbons were found. Drilling on surface structures of some of the first wells in Libya resulted in one Devonian gas well. A reported 5600 BOPD Cretaceous discovery offshore Benghazi in mid-1984 demonstrates that hydrocarbon potential exists where thick sediments have been preserved.

Ross, C.M.; Zegaar, M.N.

1985-02-01T23:59:59.000Z

340

Libyan Paleozoic: A review of the factors limiting hydrocarbon potential  

SciTech Connect (OSTI)

Of the three main Paleozoic basins - Ghadames, Murquz, and Kufra - only the Ghadames and its continuation into Algeria, the Illizi (or Fort Polignac) basin, has yielded hydrocarbons in significant quantity. The Paleozoic on the Cyrenaica platform and basement of the Sirte basin has a potential not fully considered. The paleogeography of the Paleozoic system is reviewed to illustrate the extent to which inherited and reactivated basement-controlled structures have influenced later Paleozoic sedimentation and hence the distribution of source rocks, reservoirs, and seals. In all instances, the source rocks are restricted to shales of the Tanezufft Formation or occur in the Upper Devonian Aouinet Oeunine Formation. Multiple fine-grained sequences serve as seals in all the fields. The reservoirs range from the well-cemented but highly fractured Cambrian-Ordovician Gargaf sandstones to the Acacus-Tadrart clastics to the fine-grained Lower Carboniferous Tahara Sandstone. The principal plays are associated with minor structures, and stratigraphic trapping mechanisms play a minor role. The average field size (excluding the Sirte basin) is approximately 80 million bbl of recoverable oil. Paleozoic structural plays in the Sirte basin and the Cyrenaica platform include reactivated infra-Cambrian faults. The lower Paleozoic accumulations of the Murzuq basin are tied to large structures. With the exception of local areas in the Ghadames basin, the Paleozoic succession remains a stratigraphic frontier province - still incompletely explored but with several interesting possibilities for large amounts of stratigraphically trapped hydrocarbons.

Kanes, W.H.; Mairn, A.E.M.; Aburawi, R.M.

1988-08-01T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


341

Oil source rocks in the Romanian area of the Moesian platform  

SciTech Connect (OSTI)

The Romanian area of the Moesian Platform (north of the Danube-Black Sea and east and South Carpathians Foredeep to north) represents a very important intra-plate with some new real oil prospects. With a thick sedimentary cover, especially in its northern, deepest area, the Moesian Platform offers favorable geological conditions of oil systems in the whole stratigraphic column, from Paleozoic to Upper Cenozoic (Pliocene). Having a few rich oil source rocks both in carbonatic facies (Devonian-Carboniferous, Middle Triassic, Neocomian) and argillitic ones (Silurian, early Carboniferous, Lias-Dogger, Mid-Upper Miocene), the Moesian Platform also contains very good oil reservoirs: Mid-Upper Paleozoic, Triassic, Lower Cretaceous, Upper Miocene and Pliocene. Geochemical studies on kerogen and bitumen have pointed out the most important oil source rocks, as well as the quality and quantity of expelled hydrocarbons and their relationships with oil reservoirs. Geochemical correlations between oils and source rocks have led to a better understanding of the oil pool formation with some interesting goals in the Romanian exploration strategy.

Baltes, N.; Matracaru, C.; Petrom, R.A. [Institute for Research and Technology, Prahova (Romania)

1995-08-01T23:59:59.000Z

342

Documentation of the Oil and Gas Supply Module (OGSM)  

SciTech Connect (OSTI)

The purpose of this report is to define the objectives of the Oil and Gas Supply Model (OGSM), to describe the model`s basic approach, and to provide detail on how the model works. This report is intended as a reference document for model analysts, users, and the public. Projected production estimates of US crude oil and natural gas are based on supply functions generated endogenously within National Energy Modeling System (NEMS) by the OGSM. OGSM encompasses domestic crude oil and natural gas supply by both conventional and nonconventional recovery techniques. Nonconventional recovery includes enhanced oil recovery (EOR), and unconventional gas recovery (UGR) from tight gas formations, Devonian/Antrim shale and coalbeds. Crude oil and natural gas projections are further disaggregated by geographic region. OGSM projects US domestic oil and gas supply for six Lower 48 onshore regions, three offshore regions, and Alaska. The general methodology relies on forecasted profitability to determine exploratory and developmental drilling levels for each region and fuel type. These projected drilling levels translate into reserve additions, as well as a modification of the production capacity for each region. OGSM also represents foreign trade in natural gas, imports and exports by entry region. Foreign gas trade may occur via either pipeline (Canada or Mexico), or via transport ships as liquefied natural gas (LNG). These import supply functions are critical elements of any market modeling effort.

NONE

1998-01-01T23:59:59.000Z

343

North Dakota`s Dickinson Lodgepole discovery: A Preliminary exploration model  

SciTech Connect (OSTI)

Interest in the Mississippian Lodgepole formation of North Dakota has intensified since the successful completion of the Duncan Oil Inc. 1-11 Knopik flowing 2,707 b/d of oil and 1.55 MMcfd of gas 430 cu m of oil and 43,891 cu m of gas. The play began when Conoco drilled an in-field wildcat in an attempt to establish deeper production in Dickinson oil field. The discovery well, 74 Dickinson State, was completed in a clean lower Lodgepole limestone section that is thought to represent a Waulsortian mound. The most important questions asked concerning the Lodgepole play are whether or not it will step out of the Dickinson area, what are the factors that control the development of these mounds, what controlled the development of the reservoir and trap, and how it was charged with oil. Other than the reservoir section, the most significant feature observed from wireline logs of the area is the anomalously thick Bakken formation (Mississippian-Devonian). This observation is important to understanding the Lodgepole play and can be used to help explore for similar features elsewhere in the basin. The paper describes the regional setting, the Lodgepole stratigraphy, deposition, regional equivalents, and a salt collapse model that can readily explain the features observed at the Dickinson field.

LeFever, J.A. [North Dakota Geological Survey, Grand Forks, ND (United States); Halabura, S.P. [North Rim Exploration Ltd., Saskatoon, Saskatchewan (Canada); Martiniuk, C.D. [Manitoba Energy and Mines, Winnipeg, Manitoba (Canada); Fischer, D.W.

1995-08-14T23:59:59.000Z

344

Geothermal resource assessment, South Dakota: Final report  

SciTech Connect (OSTI)

Seven geothermal aquifers in South Dakota contain an accessible resource base of about 11,207 x 10/sup 18/ J. The potentially productive geothermal aquifers are: Deadwood Formation (Cambrian), Winnipeg Formation + Red River Formation + Englewood Limestone (Ordovician through Devonian), Madison Limestone (Mississippian), Minnelusa Formation (Mississippian-Permian), Inyan Kara Group (Cretaceous), and Newcastle Sandstone (Cretaceous). The resource estimate was obtained by first using heat flow, thermal conductivity, temperature gradient, and stratigraphic data to estimate aquifer temperatures. The heat content of each aquifer was determined from the product of the volumetric heat capacity, aquifer volume, and temperature difference between the aquifer and the mean annual temperature for a 14 x 14 grid of 240 km/sup 2/ cells. Geothermal fluid temperatures range from about 120/sup 0/C in the Deadwood Formation in the Williston Basin to about 30/sup 0/C for the Newcastle Sandstone in south-central South Dakota. The area containing the resource lies largely west of the Missouri River. About 10,000 km/sup 2/ of the resource area is characterized by anomalously high heat flow values greater than 100 mW m/sup -2/.

Gosnold, W.D. Jr.

1987-07-01T23:59:59.000Z

345

Synthesis of organic geochemical data from the Eastern Gas Shales  

SciTech Connect (OSTI)

Over 2400 core and cuttings samples of Upper Devonian shales from wells in the Appalachian, Illinois, and Michigan Basins have been characterized by organic geochemical methods to provide a basis for accelerating the exploitation of this unconventional, gas-rich resource. This work was part of a program initiated to provide industry with criteria for locating the best areas for future drilling and for the development of stimulation methods that will make recovery of the resource economically attractive. The geochemical assessment shows that the shale, in much of the Appalachian, Illinois, and Michigan Basins is source rock that is capable of generating enormous quantities of gas. In some areas the shales are also capable of generating large quantities of oil as well. The limiting factors preventing these sources from realizing most of their potential are their very low permeabilities and the paucity of potential reservoir rocks. This geochemical data synthesis gives direction to future selection of sites for stimulation research projects in the Appalachian Basin by pinpointing those areas where the greatest volumes of gas are contained in the shale matrix. Another accomplishment of the geochemical data synthesis is a new estimate of the total resource of the Appalachian Basin. The new estimate of 2500 TCF is 25 percent greater than the highest previous estimates. This gives greater incentive to government and industry to continue the search for improved stimulation methods, as well as for improved methods for locating the sites where those improved stimulation methods can be most effectively applied.

Zielinski, R.E.; McIver, R.D.

1982-01-01T23:59:59.000Z

346

Gas sales starting from Indiana`s fractured New Albany shale  

SciTech Connect (OSTI)

The Indiana Department of Natural Resources, Division of Oil and Gas issued 138 drilling permits from Dec. 1, 1994, through July 31, 1996, in 17 counties in a growing play for gas in Devonian New Albany shale in southern Indiana. The permits are active in the form of locations, drilling wells, wells in the completion process, and wells producing gas in the dewatering stage. Geologically in southwestern Indiana the New Albany shale exploration play is found in three provinces. These are the Wabash platform, the Terre Haute reef bank, and the Vincennes basin. Exploration permits issued on each of these geologic provinces are as follows: Wabash platform 103, Terra Haute reef bank 33, and Vincennes basin two. The authors feel that the quantity and effectiveness of communication of fracturing in the shale will control gas production and water production. A rule of thumb in a desorption reservoir is that the more water a shale well makes in the beginning the more gas it will make when dewatered.

Minihan, E.D.; Buzzard, R.D. [Minihan/Buzzard Consulting Geologists, Fort Worth, TX (United States)

1996-09-02T23:59:59.000Z

347

Study of gas production potential of New Albany Shale (group) in the Illinois basin  

SciTech Connect (OSTI)

The New Albany Shale (Devonian and Mississippian) is recognized as both a source rock and gas-producing reservoir in the Illinois basin. The first gas discovery was made in 1885, and was followed by the development of several small fields in Harrison County, Indiana, and Meade County, Kentucky. Recently, exploration for and production of New Albany gas has been encouraged by the IRS Section 29 tax credit. To identify technology gaps that have restricted the development of gas production form the shale gas resource in the basin, the Illinois Basin Consortium (IBC), composed of the Illinois, Indiana, and Kentucky geological surveys, is conducting a cooperative research project with the Gas Research Institute (GRI). An earlier study of the geological and geochemical aspects of the New Albany was conducted during 1976-1978 as part of the Eastern Gas Shales Project (EGSP) sponsored by the Department of Energy (DOE). The current IBC/GRI study is designed to update and reinterpret EGSP data and incorporate new data obtained since 1978. During the project, relationships between gas production and basement structures are being emphasized by constructing cross sections and maps showing thickness, structure, basement features, and thermal maturity. The results of the project will be published in a comprehensive final report in 1992. The information will provide a sound geological basis for ongoing shale-gas research, exploration, and development in the basin.

Hasenmueller, N.R.; Boberg, W.S.; Comer, J.; Smidchens, Z. (Indiana Geological Survey, Bloomington (United States)); Frankie, W.T.; Lumm, D.K. (Illinois State Geological Survey, Champaign (United States)); Hamilton-Smith, T.; Walker, J.D. (Kentucky Geological Survey, Lexington (United States))

1991-08-01T23:59:59.000Z

348

Clarification of C-S relationships of marine black shales using stable isotopic composition of reduced sulfur  

SciTech Connect (OSTI)

Carbon-sulfur relationships are compared for the Miocene Monterey Formation (Santa Maria Basin, California) and the Upper Devonian New Albany Shale (Illinois Basin, Indiana). In both formations, C-S concentrations covary for samples with the lower to more intermediate organic carbon concentrations and become invariant at higher organic carbon concentrations. While the similarity of these relationships in Monterey and New Albany suggest sulfur diagenesis occurred in similar depositional environments, sulfur isotopic data clearly indicate differences in the depositional environments. In the Monterey, the most organic-rich laminated shales are characterized by isotopic enrichment of reduced S and low S ratios and indicate that sulfate reduction occurred under sulfate-limited conditions within the sediments. In the New Albany, organic-rich laminated shales exhibit isotopic depletion of reduced S coupled with low S[sub reduced]/C[sub org] and suggest sulfur diagenesis occurred under euxinic conditions. These data show that in the absence of sulfur isotopic data, misleading conclusions concerning depositional environments can be made when using C-S plots and the traditional interpretations that are associated with these types of plots.

Zaback, D.A.; Pratt, L.M. (Indiana Univ., Bloomington, IN (United States). Dept. of Geological Sciences)

1992-01-01T23:59:59.000Z

349

Petroleum potential of the Upper Ordovician Maquoketa Group in Illinois: A coordinated geological and geochemical study  

SciTech Connect (OSTI)

The Ordovician Maquoketa Group in Illinois, predominantly composed of shale, calcareous shale, and carbonates, has long been considered a potential source for Illinois basin hydrocarbons. Methods used to better define the petroleum potential of the Maquoketa in the Illinois basin were lithostratigraphic study, Rock-Eval (pyrolysis) analyses, comparison of molecular markers from whole-rock extracts and produced oil, and construction of burial history models. Organic-rich submature Maquoketa potential source rocks are present in western Illinois at shallow depths on the basin flank. Deeper in the basin in southern Illinois, Rock-Eval analyses indicate that the Maquoketa shale is within the oil window. Solvent extracts of the Maquoketa from western Illinois closely resemble the Devonian New Albany Shale, suggesting that past studies may have erroneously attributed Maquoketa-generated petroleum to a New Albany source or failed to identify mixed source oils. Subtle differences between Maquoketa and New Albany solvent extracts include differences in pristane/phytane ratios, proportions of steroids, and distribution of dimethyldibenzothiophene isomers. Maquoketa solvent extracts show little resemblance to Middle Ordovician oils from the Illinois or Michigan basins. Lithostratigraphic studies identified localized thick carbonate facies in the Maquoketa, suggesting depositional response to upper Ordovician paleostructures. Sandstone facies in the Maquoketa in southwestern Illinois offer a potential source/trap play, as well as serving as potential carrier beds for hydrocarbon migration. Maquoketa source and carrier beds may feed older Ordovician rocks in faulted areas along and south of the Cottage Grove fault system in southern Illinois.

Crockett, J.E.; Oltz, D.F. (Illinois State Geological Survey, Champaign (USA)); Kruge, M.A. (Southern Illinois Univ., Carbondale (USA))

1990-05-01T23:59:59.000Z

350

Transport and reduction of sulfate and immobilization of sulfide in marine black shales  

SciTech Connect (OSTI)

In fine-grained sediments in which the amount of reduced sulfur retained in stable phases substantially exceeds that present initially in pore waters, rates of sulfate reduction may have equaled or exceeded rates of sulfate transport, resulting in enrichment of [sup 34]S in pore waters and reduction products. Abundance and isotopic compositions of reduced sulfur compounds can be used to calculate the extent of sulfide retention and improve reconstructions of carbon-sulfur oxidation-reduction (redox) budgets. The Miocene Monterey Formation and Upper Devonian New Albany Shale represent distinct types of black shales that accumulated under different conditions of sulfate reduction. Our results suggest that the rate of sulfate reduction was controlled largely by mass transport in the Monterey and by the reduction process itself in the New Albany. Sulfide was more efficiently retained in the Monterey; thus each mole of sulfide in the New Albany represents a greater amount of sedimented organic carbon removed during sulfate reduction. 30 refs., 4 figs., 1 tab.

Zaback, D.A.; Pratt, L.M.; Hayes, J.M. (Indiana Univ., Bloomington (United States))

1993-02-01T23:59:59.000Z

351

Maintenance of high TDS in pore waters above the New Albany Shale of the Illinois Basin  

SciTech Connect (OSTI)

The TDS content of interstitial waters above the Upper Devonian New Albany Shale of the Illinois Basin, mostly sodium and chloride, increases at an average rate of 15 wt%km[sup [minus]1]. Roughly 200 My have elapsed since the youngest marine rocks of wide horizontal extent [Pennsylvania] were deposited. Regardless of the original brine-forming mechanism, the maintenance of high TDS for such a long time span is problematic because upward diffusion above the New Albany Shale should have lowered TDS if no salt dissolved above the New Albany Shale. Groundwater flow at even small rates would have lowered TDS faster than the process of diffusion alone. Calculations which take into account the effects of vertical diffusion show that the present-day salinity gradient of waters above the New Albany Shale can be explained if: (1) the salinity gradient 200 My b.p. was at least thrice as high as at the present, or (2) salt dissolved above the New Albany Shale at an average rate of about 12 m of halite column over 200 My. The code PORFLOW was used to simulate flushing of brines in a generic basin 500 km wide, 1.5 km deep [the maximum depth of the New Albany Shale], with a low basin-wide topographic gradient of 0.06%.

Ranganathan, V. (Indiana Univ., Bloomington, IN (United States). Dept. of Geological Sciences)

1992-01-01T23:59:59.000Z

352

Comparison of organic-rich shales of Pennsylvanian age in Indiana with New Albany Shale  

SciTech Connect (OSTI)

Abundant black organic-rich shales occur in rocks of Pennsylvanian age in southwestern Indiana. They have not been well characterized except for a few thin intervals in small areas, the best example being at the abandoned Mecca Quarry in west-central Indiana. Although these shales are thinner and less widespread than the organic-rich shales of the New Albany Shale (Devonian and Mississippian age) they warrant characterization because of their accessibility during strip mining of underlying coals. Organic-rich shales of Pennsylvanian age contain up to 44% organic carbon and might be considered potential oil shales. Carbon to hydrogen ratios in these shales are similar to those in the New Albany. Relatively high concentrations of certain metals occur in shales of both ages, especially where phosphate is abundant, and sulfur values for both shales range from < 1 to 6%. Sulfur values are much higher for thin pyrite-rich units. Siderite nodules are common in Pennsylvania shales, but little siderite if found in the New Albany. Dolomite, commonly ferroan, and calcite in a variety of forms are the dominant carbonates in the New Albany. Some Pennsylvanian shales may contain large fossils or mica flakes, but such coarse-grained features are uncommon in the New Albany Shale.

Shaffer, N.R.; Leininger, R.K.; Ennis, M.V.

1983-09-01T23:59:59.000Z

353

Origin of alkali-feldspar granites: An example from the Poimena Granite, northeastern Tasmania, Australia  

SciTech Connect (OSTI)

The Lottah Granite is a composite pluton of tin mineralized strongly peraluminous alkali-feldspar granite which intrudes the Poimena Granite, a major component of the mid-Devonian Blue Tier Batholith of northeastern Tasmania. Earlier workers interpreted the Lottah Granite as a metasomatised differentiate of the Poimena Granite. The Poimena Granite is a slightly peraluminous, felsic, I-type biotite granite which contains restite minerals and shows linear trends on Harker plots, both consistent with restite separation. The mineralogy, chemical variation, and isotopic characteristics of the Lottah Granite are consistent with origin as a magma genetically unrelated to the host granite. The Lottah Granite contains sanidine, albite, topaz, zinnwaldite and other minerals consistent with crystallization from a melt. Furthermore, Rb-Sr isotopic dating indicates that the Lottah Granite was emplaced about 10 Ma after the Poimena Granite, and initial Sr and Nd isotope ratios indicate that the Lottah Granite was derived from a higher-{sup 87}Sr/{sup 86}Sr, higher-{epsilon}Nd source composition. Chemical and mineralogical evolution of the Lottah Granite conform to the experimental behavior of Li-F-rich melts, and indicate a possible crystallization temperature range as extreme as 750-430{degree}C. Many other examples of alkali-feldspar granite, and much of the associated mineralization, are probably also of essentially primary magmatic origin rather than of metasomatic or hydrothermal origin as commonly interpreted. They may also be genetically unrelated to granites with which they are associated.

Mackenzie, D.E.; Black, L.P.; Sun, Shensu (Bureau of Mineral Resources, Canberra (Australia))

1988-10-01T23:59:59.000Z

354

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

SciTech Connect (OSTI)

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.

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

2013-04-01T23:59:59.000Z

355

EIA model documentation: Documentation of the Oil and Gas Supply Module (OGSM)  

SciTech Connect (OSTI)

The purpose of this report is to define the objectives of the Oil and Gas Supply Model (OGSM), to describe the model`s basic approach, and to provide detail on how the model works. This report is intended as a reference document for model analysts, users, and the public. Projected production estimates of US crude oil and natural gas are based on supply functions generated endogenously within National Energy Modeling System (NEMS) by the OGSM. OGSM encompasses domestic crude oil and natural gas supply by both conventional and nonconventional recovery techniques. Nonconventional recovery includes enhanced oil recovery (EOR), and unconventional gas recovery (UGR) from tight gas formations, Devonian shale and coalbeds. Crude oil and natural gas projects are further disaggregated by geographic region. OGSM projects US domestic oil and gas supply for six Lower 48 onshore regions, three offshore regions, and Alaska. The general methodology relies on forecasted drilling expenditures and average drilling costs to determine exploratory and developmental drilling levels for each region and fuel type. These projected drilling levels translate into reserve additions, as well as a modification of the production capacity for each region. OGSM also represents foreign trade in natural gas, imports and exports by entry region.

NONE

1997-01-01T23:59:59.000Z

356

Application of horizontal drilling to tight gas reservoirs  

SciTech Connect (OSTI)

Vertical fractures and lithologic heterogeneity are extremely important factors controlling gas flow rates and total gas recovery from tight (very low permeability) reservoirs. These reservoirs generally have in situ matrix permeabilities to gas of less than 0.1 md. Enhanced gas recovery methods have usually involved hydraulic fracturing; however, the induced vertical hydraulic fractures almost always parallel the natural fracture and may not be an efficient method to establish a good conduit to the wellbore. Horizontal drilling appears to be an optimum method to cut across many open vertical fractures. Horizontal holes will provide an efficient method to drain heterogeneous tight reservoirs even in unfractured rocks. Although many horizontal wells have now been completed in coalbed methane and oil reservoirs, very few have been drilled to exclusively evaluate tight gas reservoirs. The U.S. Department of Energy (DOE) has funded some horizontal and slanthole drilling in order to demonstrate the applicability of these techniques for gas development. Four DOE holes have been drilled in Devonian gas shales in the Appalachian basin, and one hole has been drilled in Upper Cretaceous tight sandstones in the Piceance basin of Colorado. The Colorado field experiment has provided valuable information on the abundance and openness of deeply buried vertical fractures in tight sandstones. These studies, plus higher gas prices, should help encourage industry to begin to further utilize horizontal drilling as a new exploitation method for tight gas reservoirs.

Spencer, C.W. (U.S. Geological Survey, Lakewood, CO (United States)); Lorenz, J.C. (Sandia National Labs., Albuquerque, NM (United States)); Brown, C.A. (Synder Oil Co., Denver, CO (United States))

1991-03-01T23:59:59.000Z

357

Recovery Efficiency Test Project: Phase 1, Activity report  

SciTech Connect (OSTI)

The recovery Efficiency Test well project addressed a number of technical issues. The primary objective was to determine the increased efficiency gas recovery of a long horizontal wellbore over that of a vertical wellbore and, more specifically, what improvements can be expected from inducing multiple hydraulic fractures from such a wellbore. BDM corporation located, planned, and drilled a long radius turn horizontal well in the Devonian shale Lower Huron section in Wayne County, West Virginia, demonstrating that state-of-the-art technology is capable of drilling such wells. BDM successfully tested drilling, coring, and logging in a horizontal well using air as the circulating medium; conducted reservoir modeling studies to protect flow rates and reserves in advance of drilling operations; observed two phase flow conditions in the wellbore not observed previously; cored a fracture zone which produced gas; observed that fractures in the core and the wellbore were not systematically spaced (varied from 5 to 68 feet in different parts of the wellbore); observed that highest gas show rates reported by the mud logger corresponded to zone with lowest fracture spacing (five feet) or high fracture frequency. Four and one-half inch casting was successfully installed in the borehole and was equipped to isolate the horizontal section into eight (8) zones for future testing and stimulation operations. 6 refs., 48 figs., 10 tabs.

Overbey, W.K. Jr.; Carden, R.S.; Kirr, J.N.

1987-04-01T23:59:59.000Z

358

Recovery Efficiency Test Project: Phase 1, Activity report. Volume 1: Site selection, drill plan preparation, drilling, logging, and coring operations  

SciTech Connect (OSTI)

The recovery Efficiency Test well project addressed a number of technical issues. The primary objective was to determine the increased efficiency gas recovery of a long horizontal wellbore over that of a vertical wellbore and, more specifically, what improvements can be expected from inducing multiple hydraulic fractures from such a wellbore. BDM corporation located, planned, and drilled a long radius turn horizontal well in the Devonian shale Lower Huron section in Wayne County, West Virginia, demonstrating that state-of-the-art technology is capable of drilling such wells. BDM successfully tested drilling, coring, and logging in a horizontal well using air as the circulating medium; conducted reservoir modeling studies to protect flow rates and reserves in advance of drilling operations; observed two phase flow conditions in the wellbore not observed previously; cored a fracture zone which produced gas; observed that fractures in the core and the wellbore were not systematically spaced (varied from 5 to 68 feet in different parts of the wellbore); observed that highest gas show rates reported by the mud logger corresponded to zone with lowest fracture spacing (five feet) or high fracture frequency. Four and one-half inch casting was successfully installed in the borehole and was equipped to isolate the horizontal section into eight (8) zones for future testing and stimulation operations. 6 refs., 48 figs., 10 tabs.

Overbey, W.K. Jr.; Carden, R.S.; Kirr, J.N.

1987-04-01T23:59:59.000Z

359

Tectonics and hydrocarbon potential of the Barents Megatrough  

SciTech Connect (OSTI)

Interpretation of geophysical data shows that the geological structure of the Eastern Barents Shelf, named Barents Megatrough (BM), extends sublongitudinally almost from the Baltic shield to the Franz Josef Land archipelago. The earth crust within the axis part of the BM is attenuated up to 28-30 km, whereas in adjacent areas its thickness exceeds 35 km. The depression is filled with of more than 15 km of Upper Paleozoic, Mesozoic, and Cenozoic sediments overlying a folded basement of probable Caledonian age. Paleozoic sediments, with exception of the Upper Permian, are composed mainly of carbonates and evaporites. Mesozoic-Cenozoic sediments are mostly terrigenous. The major force in the development of the BM was due to extensional tectonics. Three rifting phases are recognizable: Late Devonian-Early Carboniferous, Early Triassic, and Jurassic-Early Cretaceous. The principal features of the geologic structure and evolution of the BM during the late Paleozoic-Mesozoic correlate well with those of the Sverdup basin, Canadian Arctic. Significant quantity of Late Jurassic-Early Cretaceous basaltic dikes and sills were intruded within Triassic sequence during the third rifting phase. This was probably the main reason for trap disruption and hydrocarbon loss from Triassic structures. Lower Jurassic and Lower Cretaceous reservoir sandstones are most probably the main future objects for oil and gas discoveries within the BM. Upper Jurassic black shales are probably the main source rocks of the BM basin, as well as excellent structural traps for hydrocarbon fluids from the underlying sediments.

Baturin, D.; Vinogradov, A.; Yunov, A. (LARGE International, Moscow (USSR))

1991-08-01T23:59:59.000Z

360

Thermal modeling of Bakken Formation of Williston basin  

SciTech Connect (OSTI)

Organic geochemical analyses provide a quantitative basis on which conceptual models of thermal maturation may be built. Contour maps of maturation indices of the Mississippian-Devonian Bakken Formation of the Williston basin show anomalous patterns that are not dependent on burial depth. One such area is on the western side of the Nesson anticline. One-dimensional modeling incorporating a uniform, constant heat flow, lithology-dependent thermal conductivities, and decompaction factors indicates that these areas are less mature than surrounding regions. This is due primarily to decreasing burial depth and thinning of low-thermal-conductivity Tertiary and Cretaceous shales. Additional heat transfer to these regions may be due in part to heat transfer by fluid movement through aquifers or vertical fractures. The influence of these fluid systems is simulated through the use of a two-dimensional finite difference program. Basic assumptions are made concerning heat flow, thermal properties, and ground-water flow rates through time. Modeling of the time-temperature history is simplified by restricting the study to the time of greatest maturation, the post-Jurassic.

Anderson, D.

1986-08-01T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


361

Fracture-enhanced porosity and permeability trends in Bakken Formation, Williston basin, western North Dakota  

SciTech Connect (OSTI)

Fractures play a critical role in oil production from the Bakken Formation (Devonian and Mississippian) in the North Dakota portion of the Williston basin. The Bakken Formation in the study area is known for its low matrix porosity and permeability, high organic content, thermal maturity, and relative lateral homogeneity. Core analysis has shown the effective porosity and permeability development within the Bakken Formation to be related primarily to fracturing. In theory, lineaments mapped on the surface reflect the geometry of basement blocks and the zones of fracturing propagated upward from them. Fracturing in the Williston basin is thought to have occurred along reactivated basement-block boundaries in response to varying tectonic stresses and crustal flexure throughout the Phanerozoic. Landsat-derived lineament maps were examined for the area between 47/degrees/ and 48/degrees/ north lat. and 103/degrees/ and 104/degrees/ west long. (northern Billings and Golden Valley Counties, and western McKenzie County, North Dakota) in an attempt to identify large-scale fracture trends. In the absence of major tectonic deformation in the craton, a subtle pattern of fracturing has propagated upward through the sedimentary cover and emerged as linear topographic features visible on these large-scale, remote-sensed images.

Freisatz, W.B.

1988-07-01T23:59:59.000Z

362

Coal rank trends in western Kentucky coal field and relationship to hydrocarbon occurrence  

SciTech Connect (OSTI)

Extensive oil and gas development has occurred in the high volatile C bituminous region north of the Rough Creek fault zone, but few pools are known within the Webster syncline south of the fault zone. The rank of the Middle Pennsylvanian coals can be used to estimate the level of maturation of the Devonian New Albany Shale, a likely source rock for much of the oil and gas in the coal field. Based on relatively few data points, previous studies on the maturation of the New Albany Shale, which lies about 1 km below the Springfield coal, indicate an equivalent medium volatile bituminous (1.0-1.2% R{sub max}) rank in the Fluorspar district. New Albany rank decreases to an equivalent high volatile B/C (0.6% R{sub max}) north of the Rough Creek fault zone. Whereas the shale in the latter region is situated within the oil generation window, the higher rank region is past the peak of the level of maturation of the New Albany Shale. The significance of the New Albany reflectancy is dependent on the suppression of vitrinite reflectance in organic-rich shales. The possibility of reflectance suppression would imply that the shales could be more mature than studies have indicated.

Hower, J.C.; Rimmer, S.M.; Williams, D.A.; Beard, J.G. (Univ. of Kentucky, Lexington (USA))

1989-09-01T23:59:59.000Z

363

Effects of scale-up on oil and gas yields in a solid-recycle bed oil shale retorting process  

SciTech Connect (OSTI)

Fluidized bed pyrolysis of oil shale in a non-hydrogen atmosphere has been shown to significantly increase oil yield in laboratory-scale reactors compared to the Fischer assay by many workers. The enhancement in oil yield by this relatively simple and efficient thermal technique has led to the development of several oil shale retorting processes based on fluidized bed and related technologies over the past fifteen years. Since 1986, the Center for Applied Energy Research (CAER) has been developing one such process, KENTORT II, which is mainly tailored for the Devonian oil shales that occur in the eastern U.S. The process contains three main fluidized bed zones to pyrolyze, gasify, and combust the oil shale. A fourth fluidized bed zone serves to cool the spent shale prior to exiting the system. The autothermal process utilizes processed shale recirculation to transfer heat from the combustion to the gasification and pyrolysis zones. The CAER is currently testing the KENTORT II process in a 22.7-kg/hr process-development unit (PDU).

Carter, S.D.; Taulbee, D.N.; Vego, A. [Univ. of Kentucky, Lexington, KY (United States)

1994-12-31T23:59:59.000Z

364

Preparation of environmental analyses for synfuel and unconventional gas technologies  

SciTech Connect (OSTI)

Government agencies that offer financial incentives to stimulate the commercialization of synfuel and unconventional gas technologies usually require an analysis of environmental impacts resulting from proposed projects. This report reviews potentially significant environmental issues associated with a selection of these technologies and presents guidance for developing information and preparing analyses to address these issues. The technologies considered are western oil shale, tar sand, coal liquefaction and gasification, peat, unconventional gas (western tight gas sands, eastern Devonian gas shales, methane from coal seams, and methane from geopressured aquifers), and fuel ethanol. Potentially significant issues are discussed under the general categories of land use, air quality, water use, water quality, biota, solid waste disposal, socioeconomics, and health and safety. The guidance provided in this report can be applied to preparation and/or review of proposals, environmental reports, environmental assessments, environmental impact statements, and other types of environmental analyses. The amount of detail required for any issue discussed must, by necessity, be determined on a case-by-case basis.

Reed, R.M. (ed.)

1982-09-01T23:59:59.000Z

365

Pressurized Fluidized-Bed Hydroretorting of eastern oil shales. Final report, June 1992--January 1993  

SciTech Connect (OSTI)

The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the multi-year program, initiated in September 1987 by the US Department of Energy was to perform the research necessary to develop the pressurized fluidized-bed hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation and upgrading, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The program was divided into the following active tasks: Task 3 -- Testing of Process Improvement Concepts; Task 4 -- Beneficiation Research; Task 6 -- Environmental Data and Mitigation Analyses; and Task 9 -- Information Required for the National Environmental Policy Act. In order to accomplish all of the program objectives, tho Institute of Gas Technology (ICT), the prime contractor, worked with four other institutions: The University of Alabama/Mineral Resources Institute (MRI), the University of Alabama College of Engineering (UA), University of Kentucky Center for Applied Energy Research (UK-CAER), and Tennessee Technological University (TTU). This report presents the work performed by IGT from June 1, 1992 through January 31, 1993.

Roberts, M.J.; Mensinger, M.C.; Erekson, E.J.; Rue, D.M.; Lau, F.S. [Institute of Gas Technology, Chicago, IL (United States); Schultz, C.W.; Hatcher, W.E. [Alabama Univ., University, AL (United States). Mineral Resources Inst.; Parekh, B.K. [Kentucky Univ., Lexington, KY (United States). Center for Applied Energy Research; Bonner, W.P. [Tennessee Technological Univ., Cookeville, TN (United States)

1993-03-01T23:59:59.000Z

366

Porosity of coal and shale: Insights from gas adsorption and SANS/USANS techniques  

SciTech Connect (OSTI)

Two Pennsylvanian coal samples (Spr326 and Spr879-IN1) and two Upper Devonian-Mississippian shale samples (MM1 and MM3) from the Illinois Basin were studied with regard to their porosity and pore accessibility. Shale samples are early mature stage as indicated by vitrinite reflectance (R{sub o}) values of 0.55% for MM1 and 0.62% for MM3. The coal samples studied are of comparable maturity to the shale samples, having vitrinite reflectance of 0.52% (Spr326) and 0.62% (Spr879-IN1). Gas (N{sub 2} and CO{sub 2}) adsorption and small-angle and ultrasmall-angle neutron scattering techniques (SANS/USANS) were used to understand differences in the porosity characteristics of the samples. The results demonstrate that there is a major difference in mesopore (2-50 nm) size distribution between the coal and shale samples, while there was a close similarity in micropore (<2 nm) size distribution. Micropore and mesopore volumes correlate with organic matter content in the samples. Accessibility of pores in coal is pore-size specific and can vary significantly between coal samples; also, higher accessibility corresponds to higher adsorption capacity. Accessibility of pores in shale samples is low.

Mastalerz, Maria [Indiana Geological Survey; He, Lilin [ORNL; Melnichenko, Yuri B [ORNL; Rupp, John A [ORNL

2012-01-01T23:59:59.000Z

367

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

SciTech Connect (OSTI)

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 in 1-foot intervals from 11 cores, and approximately 260 references for these plays. A primary objective of the research was to make data and information available free to producers through an on-line data delivery model designed for public access on the Internet. The web-based application that was developed utilizes ESRI's ArcIMS GIS software to deliver both well-based and play-based data that are searchable through user-originated queries, and allows interactive regional geographic and geologic mapping that is play-based. System tools help users develop their customized spatial queries. A link also has been provided to the West Virginia Geological Survey's 'pipeline' system for accessing all available well-specific data for more than 140,000 wells in West Virginia. However, only well-specific queries by API number are permitted at this time. The comprehensive project web site (http://www.wvgs.wvnet.edu/atg) resides on West Virginia Geological Survey's servers and links are provided from the Pennsylvania Geological Survey and Appalachian Oil and Natural Gas Research Consortium web sites.

Mary Behling; Susan Pool; Douglas Patchen; John Harper

2008-12-31T23:59:59.000Z

368

Establishing the Relationship between Fracture-Related Dolomite and Primary Rock Fabric on the Distribution of Reservoirs in the Michigan Basin  

SciTech Connect (OSTI)

This topical report covers the year 2 of the subject 3-year grant, evaluating the relationship between fracture-related dolomite and dolomite constrained by primary rock fabric in the 3 most prolific reservoir intervals in the Michigan Basin (Ordovician Trenton-Black River Formations; Silurian Niagara Group; and the Devonian Dundee Formation). The characterization of select dolomite reservoirs has been the major focus of our efforts in Phase II/Year 2. Fields have been prioritized based upon the availability of rock data for interpretation of depositional environments, fracture density and distribution as well as thin section, geochemical, and petrophysical analyses. Structural mapping and log analysis in the Dundee (Devonian) and Trenton/Black River (Ordovician) suggest a close spatial relationship among gross dolomite distribution and regional-scale, wrench fault related NW-SE and NE-SW structural trends. A high temperature origin for much of the dolomite in the 3 studied intervals (based upon initial fluid inclusion homogenization temperatures and stable isotopic analyses,) coupled with persistent association of this dolomite in reservoirs coincident with wrench fault-related features, is strong evidence for these reservoirs being influenced by hydrothermal dolomitization. For the Niagaran (Silurian), a comprehensive high resolution sequence stratigraphic framework has been developed for a pinnacle reef in the northern reef trend where we had 100% core coverage throughout the reef section. Major findings to date are that facies types, when analyzed at a detailed level, have direct links to reservoir porosity and permeability in these dolomites. This pattern is consistent with our original hypothesis of primary facies control on dolomitization and resulting reservoir quality at some level. The identification of distinct and predictable vertical stacking patterns within a hierarchical sequence and cycle framework provides a high degree of confidence at this point that results will be exportable throughout the basin. Ten petrophysically significant facies have been described in the northern reef trend, providing significantly more resolution than the standard 4-6 that are used most often in the basin (e.g. Gill, 1977). Initial petrophysical characterization (sonic velocity analysis under confining pressures) shows a clear pattern that is dependent upon facies and resulting pore architecture. Primary facies is a key factor in the ultimate diagenetic modification of the rock and the resulting pore architecture. Facies with good porosity and permeability clearly show relatively slow velocity values as would be expected, and low porosity and permeability samples exhibit fast sonic velocity values, again as expected. What is significant is that some facies that have high porosity values, either measured directly or from wireline logs, also have very fast sonic velocity values. This is due to these facies having a pore architecture characterized by more localized pores (vugs, molds or fractures) that are not in communication.

G. Michael Grammer

2006-09-30T23:59:59.000Z

369

Documentation of the Oil and Gas Supply Module (OGSM)  

SciTech Connect (OSTI)

The purpose of this report is to define the objectives of the Oil and Gas Supply Model (OGSM), to describe the model`s basic approach, and to provide detail on how the model works. This report is intended as a reference document for model analysts, users, and the public. It is prepared in accordance with the Energy Information Administration`s (EIA) legal obligation to provide adequate documentation in support of its statistical and forecast reports (Public Law 93-275, Section 57(b)(2)). Projected production estimates of U.S. crude oil and natural gas are based on supply functions generated endogenously within National Energy Modeling System (NEMS) by the OGSM. OGSM encompasses domestic crude oil and natural gas supply by both conventional and nonconventional recovery techniques. Nonconventional recovery includes enhanced oil recovery (EOR), and unconventional gas recovery (UGR) from tight gas formations, Devonian shale and coalbeds. Crude oil and natural gas projections are further disaggregated by geographic region. OGSM projects U.S. domestic oil and gas supply for six Lower 48 onshore regions, three offshore regions, and Alaska. The general methodology relies on forecasted drilling expenditures and average drilling costs to determine exploratory and developmental drilling levels for each region and fuel type. These projected drilling levels translate into reserve additions, as well as a modification of the production capacity for each region. OGSM also represents foreign trade in natural gas, imports and exports by entry region. Foreign gas trade may occur via either pipeline (Canada or Mexico), or via transport ships as liquefied natural gas (LNG). These import supply functions are critical elements of any market modeling effort.

NONE

1995-10-24T23:59:59.000Z

370

ER-12-1 completion report  

SciTech Connect (OSTI)

The objective of drillhole ER-12-1 was to determine the hydrogeology of paleozoic carbonate rocks and of the Eleana Formation, a regional aquitard, in an area potentially downgradient from underground nuclear testing conducted in nearby Rainier Mesa. This objective was addressed through the drilling of well ER-12-1 at N886,640.26 E640,538.85 Nevada Central Coordinates. Drilling of the 1094 m (3588 ft) well began on July 19, 1991 and was completed on October 17, 1991. Drilling problems included hole deviation and hole instability that prevented the timely completion of this borehole. Drilling methods used include rotary tri-cone and rotary hammer drilling with conventional and reverse circulation using air/water, air/foam (Davis mix), and bentonite mud. Geologic cuttings and geophysical logs were obtained from the well. The rocks penetrated by the ER-12-1 drillhole are a complex assemblage of Silurian, Devonian, and Mississippian sedimentary rocks that are bounded by numerous faults that show substantial stratigraphic offset. The final 7.3 m (24 ft) of this hole penetrated an unusual intrusive rock of Cretaceous age. The geology of this borehole was substantially different from that expected, with the Tongue Wash Fault encountered at a much shallower depth, paleozoic rocks shuffled out of stratigraphic sequence, and the presence of an altered biotite-rich microporphyritic igneous rock at the bottom of the borehole. Conodont CAI analyses and rock pyrolysis analyses indicate that the carbonate rocks in ER-12-1, as well as the intervening sheets of Eleana siltstone, have been thermally overprinted following movement on the faults that separate them. The probable source of heat for this thermal disturbance is the microporphyritic intrusion encountered at the bottom of the hole, and its age establishes that the major fault activity must have occurred prior to 102.3+0.5 Ma (middle Cretaceous).

Russell, C.E.; Gillespie, D.; Cole, J.C.; Drellack, S.L. [and others

1996-12-01T23:59:59.000Z

371

Reflection seismic profiling in Wabash Valley fault system in southwestern Indiana  

SciTech Connect (OSTI)

During the summer of 1988 common-depth-point (CDP) reflection seismic profiling was initiated by ARPEX in southwestern Indiana in the Wabash Valley fault system. A 2.2-im (1.4-mi) east-west profile was shot across the Mt. Vernon graben in Posey County. Minihole shooting in 21-m (68.9-ft) patterns using 3.4 kg (7.5 lb) of seismic explosives distributed in five 3-m (10-ft) holes provided the energy source. Most shotholes were made with a reversible air-driven penetrating tool that was effective in dense clays. The 12-geophone array length was 43 m (141 ft), and the nominal far-trace offset was 2.1 km (7,000 ft). A 48-channel recording yielded 24-CDP coverage at 11-m (36-ft) intervals. Data were enhanced by gapped deconvolution, bandpass filtering, and CDP stack. The strongest and most continuous reflections at 0.75 and 1.6 sec are associated with the New Albany Shale (Devonian-Mississippian) and Eau Claire Formation (Cambrian), respectively. Within the Mt. Vernon graben and east of the Spenser Consolidated oil field, the depth to Eau Claire Formation apparently increases by approximately 60 m (197 ft) over a horizontal distance of 1.4 km (0.9 mi). Minor faulting east of the Spencer Consolidated field appears to be synthetic to the Hovey lake fault, which bounds the eastern side of the Mt. Vernon graben. Tentative interpretations of faulting and weak reflections from depths greater than 4.5 km (15,000 ft) may be clarified by additional data processing and by additional seismic profiling planned by ARPEX.

Rene, R.M.; Hester, N.C.; Stanonis, F.L. (Indiana Univ., Bloomington (USA))

1989-08-01T23:59:59.000Z

372

Sedimentology, diagenesis, and trapping style, Chesterian Tar Springs sandstone at Inman Field, Gallatin County, Illinois  

SciTech Connect (OSTI)

The Tar Springs Sandstone in southern Illinois is often over-looked as a pay, yet it can be a prolific producer. The Inman Field, discovered in 1940, produces from several cyclic Chesterian sandstones from structural-stratigraphic traps in the Wabash Valley Fault System of southeastern Illinois. The oil was sourced from the Devonian New Albany Shale and apparently migrated vertically along the Wabash Valley faults to its present location, thus charging many of the Chesterian and lower Pennsylvanian sands in the field. The Tar Springs Sandstone produces from stacked distributary channel sand reservoirs up to 125 feet thick which have cut up to 40 feet into laterally equivalent non-reservoir, delta-fringe facies and the underlying Glen Dean Limestone. The reservoir sands are well-sorted, fine- to medium-grained quartz arenites with less than 5% feldspar and chert. Quartz grains have quartz overgrowths. Feldspar grains are clouded in thin-section and show pronounced etching and dissolution in SEM. Diagenetic kaolinite and small amounts of illite and magnesium-rich chlorite occur in intergranular pores. Sparry, iron-rich dolomite or ankerite that fills pores in irregular millimeter-size patches, occupies up to 10% of the reservoir rock. Typical reservoir porosity ranges from 16 to 19 percent and permeability ranges from 60 to 700 md. By contrast non-reservoir delta-fringe sands typically have porosities of 6 to 12 percent and permeabilities of 1 to 20 md. Delta-fringe Tar Springs shales act as impermeable lateral and vertical seals, aiding in stratigraphic trapping.

Morse, D.G. [Illinois State Geological Survey, Champaign, IL (United States)

1996-09-01T23:59:59.000Z

373

Structure and morphology of the top of Precambrian crystalline rocks in the Illinois Basin region  

SciTech Connect (OSTI)

New basement tests and seismic-reflection profiles in the Rough Creek Graben, Wabash Valley Fault System, and other parts of the Illinois Basin have significantly advanced the authors understanding of basement morphology and tectonics. Few details of the paleotopographic component of basement morphology are known, but 100 m or more of local paleotopographic relief is documented in a few places and more than 300 m of relief is known in the western part of the basin. Based on fewer than 50 wells in the Illinois Basin that penetrate Precambrian crystalline basement, it is composed principally of granite and rhyolite porphyry with small amounts of basalt/diabase or andesite. Most of the regional morphology must be projected from structure maps of key Paleozoic horizons, including the top of Middle Ordovician Trenton (Galena), the top of Middle Devonian carbonate (base of New Albany Shale), and other horizons where data are available. The shallowest Precambrian crystalline basement within the Illinois Basin occurs in north-central Illinois where it is [minus]1,000 m MSL. Paleozoic sedimentary fill thickens southward to over 7,000 m in deeper parts of the Rough Creek Graben where crystalline basement has been depressed tectonically and by sediment loading to below [minus]7,000 m MSL. Although trends in Paleozoic strata show continued thickening in the area of the Mississippi Embayment, maximum sediment fill is preserved in the Rough Creek Graben. The general shape of the basin at the level of Precambrian crystalline basement is largely inferred from structure mapped on Paleozoic strata. Half-grabens and other block-faulted features in basement rocks are manifest in small-scale structures near the surface or have no expression in younger strata.

Sargent, M.L. (Illinois State Geological Survey, Champaign, IL (United States)); Rupp, J.A. (Indiana Geological Survey, Bloomington, IN (United States)); Noger, M.C. (Kentucky Geological Survey, Lexington, KY (United States))

1992-01-01T23:59:59.000Z

374

Ordovician carbonate formation waters in the Illinois Basin: Chemical and isotopic evolution beneath a regional aquitard  

SciTech Connect (OSTI)

Formation waters from carbonate reservoirs in the upper Ordovician Galena Group of the Illinois Basin have been analyzed geochemically to study origin of salinity, chemical and isotopic evolution, and relation to paleohydrologic flow systems. These carbonate reservoirs underlie the Maquoketa Shale Group of Cincinnatian age, which forms a regional aquitard. Cl-Br relations and Na/Br-Cl/Br systematics indicate that initial brine salinity resulted from subaerial evaporation of seawater to a point not significantly beyond halite saturation. Subsequent dilution in the subsurface by meteoric waters is supported by delta D-delta O-18 covariance. Systematic relations between Sr-87/Sr-86 and 1/Sr suggest two distinct mixing events: introduction of a Sr-87 enriched fluid from a siliciclastic source, and a later event which only affected reservoir waters from the western shelf of the basin. The second mixing event is supported by covariance between Sr-87/Sr-86 and concentrations of cations and anions; covariance between Sr and O-D isotopes suggests that the event is related to meteoric water influx. Systematic geochemical relations in ordovician Galena Group formation waters have been preserved by the overlying Maquoketa shale aquitard. Comparison with results from previous studies indicates that waters from Silurian-Devonian carbonate strata evolved in a manner similar to yet distinct from that of the Ordovician carbonate waters, whereas waters from Mississippian-Pennsylvanian strata that overlie the New Albany Shale Group regional aquitard are marked by fundamentally different Cl-Br-Na and Sr isotope systematics. Evolution of these geochemical formation-water regimes apparently has been influenced significantly by paleohydrologic flow systems.

Stueber, A.M. (Illinois Univ., Edwardsville, IL (United States)); Walter, L.M. (Univ. of Michigan, Ann Arbor, MI (United States). Dept. of Geological Sciences)

1992-01-01T23:59:59.000Z

375

Recently discovered overthrusting northeast of Llano uplift along extension of San Marcos platform: new exploration frontier in central Texas  

SciTech Connect (OSTI)

TJB Resources recently completed gravity, magnetotelluric, and seismic geophysical surveys in San Saba and Mills Counties north of the Llano uplift, west of the Ouachita Disturbed belt. Significant results show overthrusting has occurred 60-70 mi west of the Ouachita Disturbed belt. Earliest thrusting could have occurred in the Silurian-Devonian from south or southeast. Faulting reoccurs during Pennsylvanian Ouachita thrusting and again in the Late Cretaceous. The primitive Llano uplift buttressed the allochthonous rocks moving north and west. Magnetotelluric and gravity data indicate the Llano uplift is a separate and distinct isolated remnant or terrain, with numerous igneous intrusions reaching to great depths. Associated with this thrusting is a major tectonic northwest-southeast lineament located parallel to the termination of the Cretaceous rocks, outcropping on the western edge of Mills and Lampasas Counties. This lineament is documented by east-west seismic lines displaying a 0.3-sec displacement and farther southwest a 1.1-sec displacement. Paleozoic fossils were found near the surface trace of the northwest-southwest lineament as observed on the east-west seismic line. This area was previously mapped as Cretaceous. Surface inspection found Paleozoic rocks containing crinoids, spirifers, and rugose corals, with beds dipping to 45/sup 0/, contrasted with the N2/sup 0/ regional dip surrounding the lineament area. Well-log correlations from Marble Falls to Ellenberger range from 350 to 600 ft from east to west near the Llano uplift. The 60 to 70-mi frontal edge of the thrusting provides potential hydrocarbon traps along a north to northeast trend from central Texas to Oklahoma.

McMurdie, D.S.; Bryan, J.G.; Gibson, M.; King, T.; Sill, W.

1986-05-01T23:59:59.000Z

376

Approach to Recover Hydrocarbons from Currently Off-Limit Areas of the Antrim Formation, MI Using Low-Impact Technologies  

SciTech Connect (OSTI)

The goal of this project was to develop and execute a novel drilling and completion program in the Antrim Shale near the western shoreline of Northern Michigan. The target was the gas in the Lower Antrim Formation (Upper Devonian). Another goal was to see if drilling permits could be obtained from the Michigan DNR that would allow exploitation of reserves currently off-limits to exploration. This project met both of these goals: the DNR (Michigan Department of Natural Resources) issued permits that allow drilling the shallow subsurface for exploration and production. This project obtained drilling permits for the original demonstration well AG-A-MING 4-12 HD (API: 21-009-58153-0000) and AG-A-MING 4-12 HD1 (API: 21-009-58153-0100) as well as for similar Antrim wells in Benzie County, MI, the Colfax 3-28 HD and nearby Colfax 2-28 HD which were substituted for the AG-A-MING well. This project also developed successful techniques and strategies for producing the shallow gas. In addition to the project demonstration well over 20 wells have been drilled to date into the shallow Antrim as a result of this project's findings. Further, fracture stimulation has proven to be a vital step in improving the deliverability of wells to deem them commercial. Our initial plan was very simple; the 'J-well' design. We proposed to drill a vertical or slant well 30.48 meters (100 feet) below the glacial drift, set required casing, then angle back up to tap the resource lying between the base to the drift and the conventional vertical well. The 'J'-well design was tested at Mancelona Township in Antrim County in February of 2007 with the St. Mancelona 2-12 HD 3.

James Wood; William Quinlan

2008-09-30T23:59:59.000Z

377

Pressurized fluidized-bed hydroretorting of Eastern oil shales. Annual report, June 1991--May 1992  

SciTech Connect (OSTI)

The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the multi-year program, initiated in October 1987 by the US Department of Energy is to perform the research necessary to develop the Pressurized Fluidized-Bed Hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The results of the original 3-year program, which was concluded in May 1991, have been summarized in a four-volume final report published by IGT. DOE subsequently approved a 1-year extension to the program to further develop the PFH process specifically for application to beneficiated shale as feedstock. Studies have shown that beneficiated shale is the preferred feedstock for pressurized hydroretorting. The program extension is divided into the following active tasks. Task 3. testing of process improvement concepts; Task 4. beneficiation research; Task 5. operation of PFH on beneficiated shale; Task 6. environmental data and mitigation analyses; Task 7. sample procurement, preparation, and characterization; and Task 8. project management and reporting. In order to accomplish all the program objectives, the Institute of Gas Technology (IGT), the prime contractor, worked with four other institutions: the University of Alabama/Mineral Resources Institute (MRI), the University of Kentucky Center for Applied Energy Research (UK-CAER), the University of Nevada (UN) at Reno, and Tennessee Technological University (TTU). This report presents the work performed during the program extension from June 1, 1991 through May 31, 1992.

Roberts, M.J.; Mensinger, M.C.; Rue, D.M.; Lau, F.S. [Institute of Gas Technology, Chicago, IL (United States); Schultz, C.W. [Alabama Univ., University, AL (United States); Parekh, B.K. [Kentucky Univ., Lexington, KY (United States); Misra, M. [Nevada Univ., Reno, NV (United States); Bonner, W.P. [Tennessee Technological Univ., Cookeville, TN (United States)

1992-11-01T23:59:59.000Z

378

Pressurized fluidized-bed hydroretorting of Eastern oil shales  

SciTech Connect (OSTI)

The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the multi-year program, initiated in October 1987 by the US Department of Energy is to perform the research necessary to develop the Pressurized Fluidized-Bed Hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The results of the original 3-year program, which was concluded in May 1991, have been summarized in a four-volume final report published by IGT. DOE subsequently approved a 1-year extension to the program to further develop the PFH process specifically for application to beneficiated shale as feedstock. Studies have shown that beneficiated shale is the preferred feedstock for pressurized hydroretorting. The program extension is divided into the following active tasks. Task 3. testing of process improvement concepts; Task 4. beneficiation research; Task 5. operation of PFH on beneficiated shale; Task 6. environmental data and mitigation analyses; Task 7. sample procurement, preparation, and characterization; and Task 8. project management and reporting. In order to accomplish all the program objectives, the Institute of Gas Technology (IGT), the prime contractor, worked with four other institutions: the University of Alabama/Mineral Resources Institute (MRI), the University of Kentucky Center for Applied Energy Research (UK-CAER), the University of Nevada (UN) at Reno, and Tennessee Technological University (TTU). This report presents the work performed during the program extension from June 1, 1991 through May 31, 1992.

Roberts, M.J.; Mensinger, M.C.; Rue, D.M.; Lau, F.S. (Institute of Gas Technology, Chicago, IL (United States)); Schultz, C.W. (Alabama Univ., University, AL (United States)); Parekh, B.K. (Kentucky Univ., Lexington, KY (United States)); Misra, M. (Nevada Univ., Reno, NV (United States)); Bonner, W.P. (Tennessee Technological Univ., Cookeville, TN (United States))

1992-11-01T23:59:59.000Z

379

RISK REDUCTION WITH A FUZZY EXPERT EXPLORATION TOOL  

SciTech Connect (OSTI)

Incomplete or sparse information on types of data such as geologic or formation characteristics introduces a high level of risk for oil exploration and development projects. ''Expert'' systems developed and used in several disciplines and industries have demonstrated beneficial results. A state-of-the-art exploration ''expert'' tool, relying on a computerized database and computer maps generated by neural networks, is being developed through the use of ''fuzzy'' logic, a relatively new mathematical treatment of imprecise or non-explicit parameters and values. Oil prospecting risk can be reduced with the use of a properly developed and validated ''Fuzzy Expert Exploration (FEE) Tool.'' This FEE Tool can be beneficial in many regions of the U.S. by enabling risk reduction in oil and gas prospecting as well as decreased prospecting and development costs. In the 1998-1999 oil industry environment, many smaller exploration companies lacked the resources of a pool of expert exploration personnel. Downsizing, low oil prices, and scarcity of exploration funds have also affected larger companies, and will, with time, affect the end users of oil industry products in the U.S. as reserves are depleted. The FEE Tool will benefit a diverse group in the U.S., leading to a more efficient use of scarce funds, and possibly decreasing dependence on foreign oil and lower product prices for consumers. This ninth of ten semi-annual reports contains a summary of progress to date, problems encountered, plans for the next year, and an assessment of the prospects for future progress. The emphasis during the March 2003 through September 2003 period was directed toward Silurian-Devonian geology, development of rules for the fuzzy system, and on-line software.

Robert Balch

2003-10-15T23:59:59.000Z

380

Breaking into Bakken potential on the Fort Peck reservation, northeastern Montana  

SciTech Connect (OSTI)

Necessary ingredients for a Bakken play involve overpressuring, thermal maturity, stratigraphic thinning, hydrocarbon content, and the presence of fractures to free the oil. Bakken thickness varies on the reservation from 0 to 25 m. The Upper Shale Member is uniformly 3-4 m. Thickness is related to a northwest structural grain, especially in the northeast where fold axes are located parallel to the Opheim syncline. This strike is coincident with the general salt solution edge of the Devonian Prairie Evaporites. The Bakken is about 16 m thick along this dissolution boundary and may contain the necessary fracturing. Structural flexure near the Wolf Creek Nose, and especially off the northeast and eastern flanks of the Poplar dome, may have suitably fractured the Bakken as well. Well logs in this area have good resistivity separation in the Middle Siltstone Member of the Bakken, which may be used to detect fracturing in this low-porosity reservoir. Present depth of the Bakken varies from about 2,100 to 3,050 m. Electrical resistivities indicate, however, that much of the reservation's Bakken was subjected to sufficient depths to generate hydrocarbons. Other physical properties, based on porosity and gamma-ray logs, confirm that organic carbon content is adequate, if not exceptionally high. Regional and Laramide uplift, coupled with glacial erosion and rebound, probably explain the present elevation of the Bakken in this area. Significant overpressuring exists in the Bakken over at least half of the reservation as determined by sonic-log calculations and sparse drill-stem test pressures.

Monson, L.M.; Lund, D.F. (Fort Peck Tribes, Poplar, MT (United States))

1991-06-01T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


381

Characterization and simulation of an exhumed fractured petroleum reservoir. Final report, March 18, 1996--September 30, 1998  

SciTech Connect (OSTI)

An exhumed fractured reservoir located near Alligator Ridge in central Nevada provides the basis for developing and testing different approaches for simulating fractured petroleum reservoirs. The fractured analog reservoir comprises a 90 m thickness of silty limestone and shaly interbeds within the Devonian Pilot Shale. A period of regional compression followed by ongoing basin and range extension has created faults and fractures that, in tern, have controlled the migration of both oil and gold ore-forming fluids. Open pit gold mines provide access for observing oil seepage, collecting the detailed fracture data needed to map variations in fracture intensity near faults, build discrete fracture network models and create equivalent permeability structures. Fault trace patterns mapped at the ground surface provide a foundation for creating synthetic fault trace maps using a stochastic procedure conditioned by the outcrop data. Conventional simulations of petroleum production from a 900 by 900 m sub-domain within the reservoir analog illustrate the possible influence of faults and fractures on production. The consequences of incorporating the impact of different stress states (e.g., extension, compression or lithostatic) are also explored. Simulating multiphase fluid flow using a discrete fracture, finite element simulator illustrates how faults acting as conduits might be poorly represented by the upscaling procedures used to assign equivalent permeability values within reservoir models. The parallelized reservoir simulators developed during this project provide a vehicle to evaluate when it might be necessary to incorporate very fine scale grid networks in conventional reservoir simulators or to use finely gridded discrete fracture reservoir simulators.

Forster, C.B.; Nielson, D.L.; Deo, M.

1998-12-01T23:59:59.000Z

382

RISK REDUCTION WITH A FUZZY EXPERT EXPLORATION TOOL  

SciTech Connect (OSTI)

Incomplete or sparse information on types of data such as geologic or formation characteristics introduces a high level of risk for oil exploration and development projects. ''Expert'' systems developed and used in several disciplines and industries have demonstrated beneficial results. A state-of-the-art exploration ''expert'' tool, relying on a computerized database and computer maps generated by neural networks, is being developed through the use of ''fuzzy'' logic, a relatively new mathematical treatment of imprecise or non-explicit parameters and values. Oil prospecting risk can be reduced with the use of a properly developed and validated ''Fuzzy Expert Exploration (FEE) Tool.'' This FEE Tool can be beneficial in many regions of the U.S. by enabling risk reduction in oil and gas prospecting as well as decreased prospecting and development costs. In the 1998-1999 oil industry environment, many smaller exploration companies lacked the resources of a pool of expert exploration personnel. Downsizing, low oil prices, and scarcity of exploration funds have also affected larger companies, and will, with time, affect the end users of oil industry products in the U.S. as reserves are depleted. The pool of experts is much reduced today. The FEE Tool will benefit a diverse group in the U.S., leading to a more efficient use of scarce funds, and possibly decreasing dependence on foreign oil and lower product prices for consumers. This fourth of five annual reports contains a summary of progress to date, problems encountered, plans for the next year, and an assessment of the prospects for future progress. The emphasis during the April 2002 through March 2003 period was directed toward Silurian-Devonian geology, development of rules for the fuzzy system, and on-line software.

Robert Balch

2003-04-15T23:59:59.000Z

383

Pennsylvanian history of the Chautauqua Arch  

SciTech Connect (OSTI)

Westward extension of the Ozark Uplift known as the Chautauqua Arch is concealed by a Pennsylvanian cover. This cover provides an insight into its later tectonic history subsequent to its major Late Devonian uplift and truncation. Part of this arch was episodically uplifted during Pennsylvanian time in an area extending west from southwestern Missouri along the Kansas-Oklahoma border to western Montgomery County. Recent stratigraphic mapping in that county indicates moderate Late Desmoinesian to Missourian tectonism. Some strata present on both flanks of the arch are either comparatively thin or missing owing to unconformity truncation or non-deposition. Stratal loss involves the Lenapah Limestone, the Hepler and Lost Branch formations, the Cherryvale Shale and the Hertha, Drum, Dewey, Stanton and Wyandotte Limestones. Earlier movements also account for the truncation of Morrowan, Atokan and possibly some Early Desmoinesian beds over the arch. Between tectonic episodes along the arch there were periods of relative tectonic quiescence accompanied by shelf-edge carbonate banks, condensed sequences and siliciclastic sedimentation. West of Montgomery County in Chautauqua County, the widespread Late Pennsylvanian Virgilian outcrops show practically no tectonism. Therefore, the name Chautauqua Arch seems inappropriate for this Pennsylvanian arch, and the name Tri-State Arch is proposed. This arch is bounded on the north by the Cherokee Basin and on the south by the northern rise of the Arkoma Basin. Although this arch is commonly omitted on many tectonic maps, it is a stronger gravity feature than the Bourbon Arch about 50 miles northward. Both tectonic and sedimentary structures have produced much oil and gas entrapment along this arch. For example, an east-west fault south of Independence, aligned with buried Proterozoic hills, has been specially productive.

Bennison, A.P.

1993-03-01T23:59:59.000Z

384

New Albany shale flash pyrolysis under hot-recycled-solid conditions: Chemistry and kinetics, II  

SciTech Connect (OSTI)

The authors are continuing a study of recycle retorting of eastern and western oil shales using burnt shale as the solid heat carrier. Stripping of adsorbed oil from solid surfaces rather than the primary pyrolysis of kerogen apparently controls the release rate of the last 10--20% of hydrocarbons. Thus, the desorption rate defines the time necessary for oil recovery from a retort and sets the minimum hold-time in the pyrolyzer. A fluidized-bed oil shale retort resembles a fluidized-bed cat cracker in this respect. Recycled burnt shale cokes oil and reduces yield. The kerogen H/C ratio sets an upper limit on yield improvements unless external hydrogen donors are introduced. Steam can react with iron compounds to add to the H-donor pool. Increased oil yield when New Albany Shale pyrolyzes under hot-recycled-solid, steam-fluidization conditions has been confirmed and compared with steam retorting of acid-leached Colorado oil shale. In addition, with retorted, but unburnt, Devonian shale present at a recycle ratio of 3, the authors obtain 50% more oil-plus-gas than with burnt shale present. Procedures to make burnt shale more like unburnt shale can realize some increase in oil yield at high recycle ratios. Reduction with H{sub 2} and carbon deposition are possibilities that the authors have tested in the laboratory and can test in the pilot retort. Also, eastern spent shale burned at a high temperature (775 C, for example) cokes less oil than does spent shale burned at a low temperature (475 C). Changes in surface area with burn temperature contribute to this effect. 15 refs., 8 figs., 4 tabs.

Coburn, T.T.; Morris, C.J.

1990-11-01T23:59:59.000Z

385

The Mars Hill Terrane: An enigmatic southern Appalachian terrane  

SciTech Connect (OSTI)

The Mars Hill Terrane (MHT) in the Appalachian Blue Ride Belt is bordered by complex, locally reactivated thrust and strike-slip faults. On the east, the MHT is bounded by the allochthonous, ensimatic Toe Terrane (TT) across the diachronous, ductile Holland Mountain-Soque River Fault System. The MHT is separated on the northwest from ensialic Laurentian basement (LB), by the Fries-Hayesville Fault System. On the south, the MHT is truncated by the Shope Fork Fault. The MHT is characterized by migmatitic biotite-pyroxene-hornblende gneiss, but contains 1--1.8 b.y. old quartz-feldspar gneisses, plus ultramafic rocks, calc-silicate rocks, mica schists and gneisses, and Neoproterozoic Bakersville gabbros. This rock assemblage contrasts with that of the adjoining terranes. The only correlative units between the MHT and adjoining terranes are Neoproterozoic gabbro, Ordovician-Devonian granitoid plutons, and ultramafic rocks. Gabbro links the MHT with LB rocks. Apparently similar calc-silicate rocks differ petrographically among terranes. During Taconic or Acadian events, both the TT and MHT reached amphibolite to granulite metamorphic grade, but the LB did not exceed greenschist grade. The data conflict. The O-D plutons, ultramafic rocks, and metamorphic histories suggest that the TT had docked with the MHT by Ordovician time. The premetamorphic character of the Holland Mtn.-Soque River Fault System supports that chronology. Neoproterozoic gabbros suggest a MHT-LB link by Cambrian time, but the LB experienced neither O-D plutonism nor Paleozoic amphibolite-granulite facies metamorphism.

Raymond, L.A.; Johnson, P.A. (Appalachian State Univ., Boone, NC (United States). Dept. of Geology)

1994-03-01T23:59:59.000Z

386

Factors controlling Simpson Group production in central Oklahoma  

SciTech Connect (OSTI)

The distribution of oil production from within the Simpson Group has been considered enigmatic because all of the sandstone members are present throughout the study area, but some fields produce from all of the sandstone members and others produce from only on horizon. The Simpson shales are not capable of generating hydrocarbons and the oil produced from the Simpson Group probably originated from the Devonian/Mississippian Woodford Shale. The McClain County fault juxtaposed the Woodford shale with the Simpson Group, which enabled lateral oil migration from the Woodford into the Simpson Group sandstones. Also, tortuous migration pathways allowed Woodford oil to ultimately accumulate in Simpson reservoirs which involve downthrown younger rocks adjacent to upthrown older rocks. Slight structural movements occurred contemporaneously with the deposition of the Simpson Group creating semi-parallel northeast-southwest-oriented thick and thin trends. Local structural movements were active during part or all of Simpson deposition. This created stratigraphic variations in the individual Simpson Group formations which cause the apex of a field to migrate (or even vanish) with depth. Consequently, lower Simpson structures may not be reflected by upper Simpson structures and, conversely, upper Simpson structures may not continue with depth. Variations in Viola deposition enhanced the vertical discontinuity of structures within the study area so that mapped Viola structures may not reflect underlying Simpson structures. Furthermore, a dramatic change in the orientation of the structural grain began to appear in the late Ordovician (Viola). Subsequent movements enhanced this later structural orientation, producing two acute structural trends that control the entrapment of oil. This study demonstrates that the dual structural imprint is probably the single most important factor in controlling the distribution and accumulation of hydrocarbons within the study area.

Smith, P.W.

1993-09-01T23:59:59.000Z

387

Regional-scale flow of formation waters in the Williston basin  

SciTech Connect (OSTI)

The Williston basin is a structurally simple intracratonic sedimentary basin that straddles the United States-Canada border east of the Rocky Mountains and that contains an almost continuous stratigraphic record since the Middle Cambrian. Based on the wealth of data generated by the oil industry, the regional-scale characteristics of the flow of formation waters were analyzed for the Canadian side of the basin, and integrated with previous studies performed on the American side. Several aquifers and aquifer systems identified in the basin were separated by intervening aquitards and aquicludes. The Basal, Devonian, and Mannville (Dakota) aquifers are open systems, being exposed at the land surface in both recharge and discharge areas. Recharge takes place in the west-southwest at relatively high altitude in the Bighorn and Big Snowy mountains and at the Black Hills and Central Montana uplifts, whereas discharge takes place in the east and northeast at outcrop along the Canadian Precambrian shield in Manitoba and the Dakotas. The Mississippian and Pennsylvanian aquifer systems are semi-open, cropping out only in the west-southwest where they recharge, but discharging in the northeast into adjacent aquifers through confining aquitards. On regional and geological scales, the entire system seems to be at steady-state, although locally transient flow is present in places due to water use and hydrocarbon exploitation, and to some erosional rebound in the uppermost confining shales. On the western flank of the basin, the interplay between the northeastward structural downdip direction and the northeastward flow of formation waters creates conditions favorable for hydrodynamic oil entrapment.

Bachu, S. [Alberta Department of Energy, Edmonton (Canada); Hitchon, B. [Hitchion Geochemical Services Ltd., Alberta (Canada)

1996-02-01T23:59:59.000Z

388

Numerical modeling of deep groundwater flow and heat transport in the Williston Basin  

SciTech Connect (OSTI)

A numerical modeling approach has been used to evaluate quantitatively the effects of fluid flow on contemporary heat flow in an intracratonic basin. The authors have selected the Williston basin for this hydrodynamic study because of the opportunity it presents to assess the relation of deep groundwater flow to basin geothermics and the associated features of diagenesis and petroleum accumulation. The finite element method is used to solve the coupled equations of fluid flow and heat transport in two-dimensional sections of the basin. Both the fluid- and heat-flow regime are assumed to be at steady state, and the fluid flow is driven primarily by the water-table relief which is taken to be a subdued replica of land-surface topography. Buoyancy forces may also affect flow through fluid density gradients created by temperature and salinity effects. Three southwest-northwest oriented sections across the basin were modeled using available and estimated parameter data. The predicted flow patterns are most strongly affected by the topography, but the Devonian salt unit and Cretaceous shale unit exert some control. Cross-formational flow is especially important near the downdip, solution edge of the salt beds. Flow rates rarely exceed 0.5 m/year in the deep-central part of the basin, yet there does exist a marked effect on heat flow, albeit subdued by the blanket effect of the low-permeability Cretaceous shales. The regional effect of the topography-driven flow system is reflected in present-day salinity patterns and heat-flow data.

Garven, G.; Vigrass, L.

1985-01-01T23:59:59.000Z

389

Petroleum exploration of Winnipegosis Formation in north-central North Dakota (Williston basin)  

SciTech Connect (OSTI)

The Winnipegosis Formation (Middle Devonian) in north-central Dakota has the greatest potential for large oil reserves in the Williston basin. The Winnipegosis carbonate (50 to 325 ft thick) was deposited in the southeast end of the Elk Point restricted sea. During Winnipegosis deposition, the Williston basin could be divided into two distinct environments: (1) a deep starved basin with accompanying pinnacle reefs separated by interreef, laminated limestone and (2) a surrounding carbonate shelf. Within the carbonate shelf are patch reefs, banks, and tidal flats. Overlying the Winnipegosis carbonate is the Prairie Formation, which has a basal anhydrite (0 to 70 ft thick) and an overlying salt (0 to 650 ft thick). These were deposited in a regressive phase of the Elk Point sea and act as seals for Winnipegosis oil entrapment. Currently, oil production from the Winnipegosis in the Williston basin is from stratigraphic traps and from small structures on the carbonate shelf. The most significant accumulation to date is Temple field, in which 11 wells produce from +/- 20 ft of Winnipegosis dolomite. The pinnacle reef environment has potential for significant oil reserves from 250-ft thick reefs covering 160 ac or less. Two pinnacle reefs have had free-oil recoveries from thin pay zones. The Rainbow/Zama fields in northwest Alberta have an ultimate reserve of more than 1 billion bbl of oil from Keg River reefs, which are correlative and similar to the Winnipegosis reefs in North Dakota. The strong seismic reflection that originates from the Winnipegosis-Prairie evaporite interface provides an excellent means of detecting Winnipegosis reefs. Amplitude of the Winnipegosis reflection is reduced dramatically over the reefs. The resulting dim spot is one criteria used in identifying reefs.

Guy, W.J. Jr.; Braden, K.W.

1986-08-01T23:59:59.000Z

390

Occurrence of pore-filling halite in carbonate rocks, Nesson Anticline, Williston basin, North Dakota  

SciTech Connect (OSTI)

Clear, colorless pore-filling halite of late diagenetic origin occurs locally in the Devonian Dawson Bay, Winnipegosis, and Ashern Formations, the Silurian Interlake Formation, and the Ordovician Red River Formation. The halite occludes a variety of pore types and individual pores are filled with single crystals or aggregates of only a few crystals. This halite is present in quantities ranging from a trace to approximately 12%. Cores from McGregor field, Williams County, show the Winnipegosis Formation consists of mixed-skeletal lime wackestones and mudstones. These contain vugs up to 4 in. (10 cm) in size, intraparticle pores, and shelter porosity within pelecypod shells, up to 4 in. (10 cm) in size, which are occluded with halite. Halite also fills common small discontinuous vertical fractures. The upper 200 ft (61 m) of the Interlake Formation locally exhibits the most striking occurrences of pore-filling halite. These dolostones consist predominantly of intraclast-peloid mudstones, wackestones, packstones, occasional grainstones, algal boundstones, and solution-collapse breccias containing vug, fenestral, interparticle, shelter, intercrystalline, moldic, channel, breccia, and fracture porosity types. All porosity types, except intercrystalline, can be halite filled. A rare occurrence of pore-filling halite exists in Red River cores from Blue Buttes field, McKenzie County, where a dolomitic, mixed-skeletal, lime mudstone and wackestone lithofacies contains vugs, discontinuous vertical fractures, and intraparticle porosity types occluded with halite. In most occurrences, the pore systems were noneffective prior to halite infilling and had no potential as hydrocarbon reservoirs. However, it has been demonstrated that halite plugging in the Interlake Formation has locally formed updip seals to hydrocarbon migration.

Bucher, E.J.

1988-07-01T23:59:59.000Z

391

A chemical kinetic model of hydrocarbon generation from the Bakken Formation, Williston Basin, North Dakota  

SciTech Connect (OSTI)

This report describes a model of hydrocarbon generation and expulsion in the North Dakota portion of the Williston Basin. The modeling incorporates kinetic methods to simulate chemical reactions and 1-dimensional conductive heat flow models to simulate thermal histories of the Mississippian-Devonian Bakken Formation source rock. We developed thermal histories of the source rock for 53 wells in the basin using stratigraphic and heat flow data obtained by the University of North Dakota. Chemical kinetics for hydrocarbon generation, determined from Pyromat pyrolysis, were, then used with the diennal histories to calculate the present day value of the Rock-Eval T{sub max} for each well. The calculated Rock-Eval T{sub max} values agreed with measured values within amounts attributable to uncertainties in the chemical kinetics and the heat flow. These optimized thermal histories were then used with a more detailed chemical kinetic model of hydrocarbon generation and expulsion, modified from a model developed for the Cretaceous La Luna shale, to simulate pore pressure development and detailed aspects of the hydrocarbon chemistry. When compared to values estimated from sonic logs, the pore pressure calculation underestimates the role of hydrocarbon generation and overestimates the role of compaction disequilibrium, but it matches well the general areal extent of pore pressures of 0.7 times lithostatic and higher. The simulated chemistry agrees very well with measured values of HI, PI, H/C atomic ratio of the kerogen, and Rock-Eval S1. The model is not as successful in simulating the amount of extracted bitumen and its saturate content, suggesting that detailed hydrous pyrolysis experiments will probably be needed to further refine the chemical model.

Sweeney, J.J.; Braun, R.L.; Burnham, A.K. [Lawrence Livermore National Lab., CA (United States); Gosnold, W.D. [North Dakota Univ., Grand Forks, ND (United States)

1992-10-01T23:59:59.000Z

392

Big Stick/Four Eyes fields: structural, stratigraphic, and hydrodynamic trapping within Mission Canyon Formation, Williston basin  

SciTech Connect (OSTI)

The Mississippian Mission Canyon formation of the Williston basin is the region's most prolific oil producing horizon. Big Stick/Four Eyes is among the most prolific of the Mission Canyon fields. Primary production from 87 wells is projected to reach 47 million bbl of oil. An additional 10-20 million bbl may be recovered through waterflooding. The complex was discovered in 1977 by the Tenneco 1-29 BN, a wildcat with primary objectives in the Devonian Duperow and Ordovician Red River Formations. A series of Mission Canyon discoveries followed in the Big Stick, Treetop, T-R, and Mystery Creek fields. Early pressure studies showed that these fields were part of an extensive common reservoir covering 44.75 mi/sup 2/ (115.91 km/sup 2/). The reservoir matrix is formed from restricted marine dolostones deposited on a low-relief ramp. Landward are algal-laminated peritidal limestones and saline and supratidal evaporites of a sabkhalike shoreline system. Open-marine limestones, rich in crinoids, brachiopods, and corals, mark the seaward limit of reservoir facies. Regressive deposition placed a blanket of anhydrite over the carbonate sequence providing a seal for the reservoir. Lateral trapping is accomplished through a combination of processes. Upper reservoir zones form belts of porosity that parallel the northeasterly trending shoreline. The trend is cut by the northward plunging Billings anticline, which provides structural closure to the north. Facies changes pinch out porosity to the south and east. Trapping along depositional strike to the southwest is only partially controlled by stratigraphic or structural factors. A gentle tilt of 25 ft per mi (5 m per km) occurs in the oil-water contact to the east-northeast, due to freshwater influx from Mississippian outcrop on the southern and southwestern basin margins.

Breig, J.J.

1988-07-01T23:59:59.000Z

393

Williston basin Seislog study  

SciTech Connect (OSTI)

This paper describes the results of Seislog (trade name) processing and interpretation of an east-west line in the North Dakota region of the Williston basin. Seislog processing involves inversion of the seismic trace data to produce a set of synthetic sonic logs. These resulting traces, which incorporate low-frequency velocity information, are displayed in terms of depth and isotransit times. These values are contoured and colored, based on a standard stratigraphic color scheme. The section studied is located just north of a dual producing oil pool from zones in the Ordovician Red River and Devonian Duperow Formations. A sonic log from the Long Creek 1 discovery well was digitized and filtered to match the frequency content of the original seismic data. This allows direct comparison between units in the well and the pseudosonic log (Seislog) trace nearest the well. Porosity development and lithologic units within the lower Paleozoic stratigraphic section can be correlated readily between the well and Seislog traces. Anomalous velocity zones within the Duperow and Red River Formations can be observed and correlated to producing intervals in the nearby wells. These results emphasize the importance of displaying inversion products that incorporate low-frequency data in the search for hydrocarbons in the Williston basin. The accumulations in this region are local in extent and are difficult to pinpoint by using conventional seismic data or displays. Seislog processing and displays provide a tested method for identification and delineation of interval velocity anomalies in the Red River and Duperow stratigraphic sections. These techniques can significantly reduce risks in both exploration and delineation drilling of these types of targets.

Mummery, R.C.

1985-02-01T23:59:59.000Z

394

Recognition of hydrocarbon expulsion using well logs: Bakken Formation, Williston Basin  

SciTech Connect (OSTI)

The Upper Mississippian-Lower Devonian Bakken Formation forms a source/carrier/reservoir system in the Williston basin. Hydrocarbon expulsion within the Bakken has been identified by overlaying sonic and resistivity logs. Typically, these curves track in organically lean, water-saturated mudrocks because both respond mainly to porosity; however, in thermally mature organic-rich rocks and hydrocarbon reservoirs or carrier beds, the curves separate due to the anomalously high resistivity associated with replacement of pore water by hydrocarbons. Sonic/resistivity-log overlays for wells throughout the Montana and North Dakota parts of the Williston basin reveal significant increases and maximum in-curve separation within the middle siltstone member of the Bakken at subsurface temperatures of about 170 and 200{degree}F, respectively. Sequence-stratigraphic characteristics of the Bakken define the framework within which the expulsion process operates. The organic-rich upper and lower shale members represent the transgressive and early highstand systems tracts of two adjacent depositional sequences. A sequence boundary within the intervening middle siltstone member separates nearshore siltstone and sandstone of the late highstand systems tract in the lower sequence from cross-bedded subtidal to intertidal sandstones of the lowstand systems tract in the upper sequence. Reservoir properties vary across this sequence boundary. The authors attribute the log separation in the siltstone member to hydrocarbons expelled from the adjacent shales. Abrupt shifts in several geochemical properties of the shale members, indicative of hydrocarbon generation occur over the same subsurface temperature range as the rapid increase in log separation in the middle siltstone, thus indicating the contemporaneity of generation and expulsion.

Cunningham, R.; Zelt, F.B.; Morgan, S.R.; Passey, Q.R. (Exxon Production Research Co., Houston, TX (USA)); Snavely, P.D. III; Webster, R.L. (Exxon Co., U.S.A., Houston, TX (USA))

1990-05-01T23:59:59.000Z

395

Ancestral Nesson anticline and associated geothermal anomalies: Enhanced hydrocarbon generation controlled by crustal structure  

SciTech Connect (OSTI)

Hydrocarbon generation in the Williston basin is influenced by crustal motions and geothermal gradient anomalies associated with the ancestral Nesson anticline, a long-lived crustal structure located along 103{degree} longitude. This structure and its effects are particularly important in Canada where most petroleum source rocks were not sufficiently buried to have generated hydrocarbons in a normal geothermal gradient environment. High geothermal gradients associated with this structure raise the oil window and expand the region of source rock thermal maturity. Ancestral Nesson structure subsided differentially throughout the Phanerozoic, controlling paleobathymetry and facies over its crest. During the Upper Ordovician the structure was positive; rich potential petroleum source rocks were deposited on the western flank of the structure, generally excluding them from the zone of elevated heat flows. The total petroleum potential of this oil-source system exceeds 5.5 billion bbl of oil equivalent in Canada alone. Unfortunately, its exclusion from the maturation anomaly results in no more than 200 million bbl of oil being expelled from these sources. During the Middle Devonian, the structure was a negative feature that formed a starved subbasin separating the Winnipegosis and Elm Point carbonate shelves. Rich potential petroleum source rocks that accumulated on the crest of the structure at that time now overlie the region of elevated heat that flows and enhanced hydrocarbon maturation. Two billion barrels of oil are estimated to have been expelled from this source rock. Understanding the history and tectonics of the ancestral Nesson anticline is fundamental to a correct appraisal of hydrocarbon resources in the Williston basin.

Osadetz, K.G.; Snowdon, L.R. (Geological Survey of Canada, Calgary, Alberta (Canada))

1989-09-01T23:59:59.000Z

396

The development of an integrated multistage fluid bed retorting process. [Kentort II process  

SciTech Connect (OSTI)

This report summarizes the progress made on the development of an integrated multistage fluidized bed retorting process (KENTORT II) during the period of April 1, 1992 through June 30, 1992. The KENTORT II process includes integral fluidized bed zones for pyrolysis, gasification, and combustion of the oil shale. The purpose of this program is to design and test the KENTORT II process at the 50-lb/hr scale. The raw oil shale sample for the program was mined, prepared, characterized and stored this quarter. The shale that was chosen was from the high-grade zone of the Devonian Cleveland Member of the Ohio Shale in Montgomery County, Kentucky. The shale was mined and then transported to the contractor's crushing facility where it was crushed, double-screened, and loaded into 85 55-gal barrels. The barrels, containing a total of 25-30 tons of shale, were transported to the (CAER) Center for Applied Energy Research where the shale was double-screened, analyzed and stored. A major objective of the program is the study of solid-induced secondary coking and cracking reactions. A valved fluidized bed reactor has been the primary apparatus used for this study prior to this quarter, but two additional techniques have been initiated this quarter for the study of other aspects of this issue. First, the two-stage hydropyrolysis reactor at the University of Strathclyde, Glasgow, Scotland, was used to study the coking tendency of shale oil vapors under a wide range of pyrolysis and hydropyrolysis conditions. This work enabled us to examine secondary reactions under high pressure conditions (up to 150 bar) which were previously unavailable. Second, the development of a fixed bed reactor system was initiated at the CAER to study the coking and cracking characteristics of model compounds. A fixed bed apparatus was necessary because the conversion of model compounds was too low in the fluidized bed apparatus.

Carter, S.D.; Taulbee, D.N.; Robl, T.L.; Hower, J.C.

1992-08-01T23:59:59.000Z

397

The development of an integrated multistage fluid bed retorting process. Technical report, April 1, 1992--June 30, 1992  

SciTech Connect (OSTI)

This report summarizes the progress made on the development of an integrated multistage fluidized bed retorting process (KENTORT II) during the period of April 1, 1992 through June 30, 1992. The KENTORT II process includes integral fluidized bed zones for pyrolysis, gasification, and combustion of the oil shale. The purpose of this program is to design and test the KENTORT II process at the 50-lb/hr scale. The raw oil shale sample for the program was mined, prepared, characterized and stored this quarter. The shale that was chosen was from the high-grade zone of the Devonian Cleveland Member of the Ohio Shale in Montgomery County, Kentucky. The shale was mined and then transported to the contractor`s crushing facility where it was crushed, double-screened, and loaded into 85 55-gal barrels. The barrels, containing a total of 25-30 tons of shale, were transported to the (CAER) Center for Applied Energy Research where the shale was double-screened, analyzed and stored. A major objective of the program is the study of solid-induced secondary coking and cracking reactions. A valved fluidized bed reactor has been the primary apparatus used for this study prior to this quarter, but two additional techniques have been initiated this quarter for the study of other aspects of this issue. First, the two-stage hydropyrolysis reactor at the University of Strathclyde, Glasgow, Scotland, was used to study the coking tendency of shale oil vapors under a wide range of pyrolysis and hydropyrolysis conditions. This work enabled us to examine secondary reactions under high pressure conditions (up to 150 bar) which were previously unavailable. Second, the development of a fixed bed reactor system was initiated at the CAER to study the coking and cracking characteristics of model compounds. A fixed bed apparatus was necessary because the conversion of model compounds was too low in the fluidized bed apparatus.

Carter, S.D.; Taulbee, D.N.; Robl, T.L.; Hower, J.C.

1992-08-01T23:59:59.000Z

398

Completion Report for Well ER-12-2  

SciTech Connect (OSTI)

Well ER-12-2 was drilled for the U.S. Department of Energy, National Nuclear Security Administration Nevada Site Office, in support of the Nevada Environmental Restoration Project at the Nevada Test Site, Nye County, Nevada. The well was drilled from November 2002 to January 2003 as part of a hydrogeologic investigation program for the Yucca Flat Corrective Action Unit. The overall purpose of the well was to gather subsurface data to better characterize the hydrogeology in the northwestern portion of Yucca Flat. The well was drilled to total measured depth of 2,097.9 meters. The 131.1-centimeter-diameter borehole was left open (i.e., uncased) below the base of the intermediate casing at 901.6 meters. A piezometer string was installed outside the surface casing to a depth of 176.4 meters to monitor a zone of perched water. Data gathered during and shortly after hole construction include composite drill cuttings samples collected every 3 meters, sidewall core samples from 7 depths, various geophysical logs, and water level measurements. These data indicate that the well penetrated, in descending order, 137.5 meters of Quaternary and Tertiary alluvium, 48.8 meters of Tertiary volcanic rocks, 289.6 meters of Mississippian Chainman Shale, and 1,622.5 meters of Mississippian and Upper Devonian Eleana Formation consisting of shale, argillite, sandstone, quartzite, and limestone. Forty-seven days after the well was drilled the water level inside the main hole was tagged at the depth of 65.43 meters, and the water level inside the piezometer string was tagged at 127.14 meters.

Bechtel Nevada

2004-11-01T23:59:59.000Z

399

Summary of Research through Phase II/Year 2 of Initially Approved 3 Phase/3 Year Project - Establishing the Relationship between Fracture-Related Dolomite and Primary Rock Fabric on the Distribution of Reservoirs in the Michigan Basin  

SciTech Connect (OSTI)

This final scientific/technical report covers the first 2 years (Phases I and II of an originally planned 3 Year/3 Phase program). The project was focused on evaluating the relationship between fracture-related dolomite and dolomite constrained by primary rock fabric in the 3 most prolific reservoir intervals in the Michigan Basin. The characterization of select dolomite reservoirs was the major focus of our efforts in Phases I and II of the project. Structural mapping and log analysis in the Dundee (Devonian) and Trenton/Black River (Ordovician) suggest a close spatial relationship among gross dolomite distribution and regional-scale, wrench fault-related NW-SE and NE-SW structural trends. A high temperature origin for much of the dolomite in these 2 studied intervals (based upon fluid inclusion homogenization temperatures and stable isotopic analyses,) coupled with persistent association of this dolomite in reservoirs coincident with wrench fault-related features, is strong evidence for these reservoirs being influenced by hydrothermal dolomitization. In the Niagaran (Silurian), there is a general trend of increasing dolomitization shelfward, with limestone predominant in more basinward positions. A major finding is that facies types, when analyzed at a detailed level, are directly related to reservoir porosity and permeability in these dolomites which increases the predictability of reservoir quality in these units. This pattern is consistent with our original hypothesis of primary facies control on dolomitization and resulting reservoir quality at some level. The identification of distinct and predictable vertical stacking patterns within a hierarchical sequence and cycle framework provides a high degree of confidence at this point that the results should be exportable throughout the basin. Much of the data synthesis and modeling for the project was scheduled to be part of Year 3/Phase III, but the discontinuation of funding after Year 2 precluded those efforts. Therefore, the results presented in this document are not final, and in many cases represent a report of 'progress to date' as numerous tasks were scheduled to extend into Year 3.

G. Grammer

2007-09-30T23:59:59.000Z

400

Comparison of the Wymark CO2 Reservoir with the Midale Beds at the Weyburn CO2 Injection Project  

SciTech Connect (OSTI)

The Devonian carbonates of the Duperow Formation on the western flank of the Williston Basin in southwest Saskatchewan contain natural accumulations of CO{sub 2}, and may have done so for as long as 50 m.y. in the views of some investigations. These carbonate sediments are characterized by a succession of carbonate cycles capped by anhydrite-rich evaporites that are thought to act as seals to fluid migration. The Weyburn CO{sub 2} injection site lies 400 km to the east in a series of Mississippian carbonates that were deposited in a similar depositional environment. That natural CO{sub 2} can be stored long-term within carbonate strata has motivated the investigation of the Duperow rocks as a potential natural analogue to storage of anthropogenic CO{sub 2} that may ultimately provide additional confidence for CO{sub 2} sequestration in carbonate lithologies. For the Duperow strata to represent a legitimate analog for Midale injection and storage, the similarity in lithofacies, whole rock compositions, mineral compositions and porosity with the Midale Beds must be established. Previous workers have demonstrated the similarity of the lithofacies at both sites. Here we compare the whole rock compositions, mineralogy and mineral compositions. The major mineral phases at both locales are calcite, dolomite and anhydrite. In addition, accessory pyrite, fluorite and celestine are also observed. The distribution of porosity in the Midale Vuggy units is virtually identical to that of the Duperow Formation, but the Marly units of the Midale have significantly higher porosity. The Duperow Formation is topped by the Dinesmore evaporite that is particularly rich in anhydrite, and often contains authigenic K-feldspar. The chemistry of dolomite and calcite from the two localities also overlaps. Silicate minerals are in low abundance within the analyzed Duperow samples, < 3 wt% on a normative basis, with quartz the only phase identifiable in x-ray diffraction patterns. The Midale Beds contain significantly higher silica/silicate concentrations, but the silicate minerals observed, K-feldspar and quartz, are unlikely to participate in carbonate mineral precipitation due to the absence of alkaline earths. Hence, physical and solution trapping are likely to be the primary trapping mechanisms at both sites. Given the similarity of mineral constituents, whole rock and mineral chemistry, reactive transport models developed for the Weyburn site should also be applicable to the Duperow lithologies.

Ryerson, F; Johnson, J

2010-11-22T23:59:59.000Z

Note: This page contains sample records for the topic "utica marcellus devonian" from the National Library of EnergyBeta (NLEBeta).
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they are not comprehensive nor are they the most current set.
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to obtain the most current and comprehensive results.


401

Deep Resistivity Structure of Rainier Mesa-Shoshone Mountain, Nevada Test Site, Nevada  

SciTech Connect (OSTI)

The U. S. Department of Energy (DOE) and the National Nuclear Security Administration (NNSA) at their Nevada Site Office (NSO) are addressing groundwater contamination resulting from historical underground nuclear testing through the Environmental Management (EM) program and, in particular, the Underground Test Area (UGTA) project. During 2005, the U.S. Geological Survey (USGS), funded by the DOE and NNSA-NSO, collected and processed data from twenty-six Magnetotelluric (MT) and Audio-Magnetotelluric (AMT) sites at the Nevada Test Site. Data stations were located in and near Rainier Mesa and Shoshone Mountain to assist in characterizing the pre-Tertiary geology in those areas. These new stations extend to the west the hydrogeologic study that was conducted in Yucca Flat in 2003. This work has helped to refine the character, thickness, and lateral extent of pre Tertiary confining units. In particular, a major goal has been to define the upper clastic confining unit (UCCU late Devonian to Mississippian-age siliciclastic rocks assigned to the Eleana Formation and Chainman Shale(Bechtel Nevada, 2006)) in the Yucca Flat area and west towards Shoshone Mountain in the south, east of Buckboard Mesa, and onto Rainier Mesa in the north. The Nevada Test Site magnetotelluric data interpretation presented in this report includes the results of detailed two-dimensional (2 D) resistivity modeling for each profile (including alternative interpretations) and gross inferences on the three dimensional (3 D) character of the geology within the region. The character, thickness, and lateral extent of the Chainman Shale and Eleana Formation that comprise the Upper Clastic Confining Unit (UCCU) are generally characterized in the upper 5 km. The interpretation is not well determined where conductive TCU overlies conductive Chainman Shale, where resistive Eleana Formation overlies resistive LCA units, or where resistive VTA rock overlies units of the Eleana Formation. The nature of the volcanic units in the west has been refined as are large and small fault structures such as the CP Thrust Fault, the Carpetbag Fault, and the Yucca Fault that cross Yucca Flat. The subsurface electrical resistivity distribution and inferred geologic structures determined by this investigation should help constrain the hydrostratigraphic framework model that is under development for the Rainier Mesa/Shoshone Mountain Corrective Action Unit and areas to the west and in understanding the effects on ground-water flow in the area.

Theodore H. Asch; Brian D. Rodriguez; Jay A. Sampson; Jackie M. Williams; Maryla Deszcz-Pan

2006-12-12T23:59:59.000Z

402

Deep Resistivity Structure of Yucca Flat, Nevada Test Site, Nevada.  

SciTech Connect (OSTI)

The Department of Energy (DOE) and the National Nuclear Security Administration (NNSA) at their Nevada Site Office are addressing groundwater contamination resulting from historical underground nuclear testing through the Environmental Management program and, in particular, the Underground Test Area project. One issue of concern is the nature of the somewhat poorly constrained pre Tertiary geology and its effects on ground-water flow in the area adjacent to a nuclear test. Ground water modelers would like to know more about the hydrostratigraphy and geologic structure to support a hydrostratigraphic framework model that is under development for the Yucca Flat Corrective Action Unit (CAU). During 2003, the U.S. Geological Survey, supported by the DOE and NNSA-NSO, collected and processed data from 51 magnetotelluric (MT) and audio-magnetotelluric (AMT) stations at the Nevada Test Site in and near Yucca Flat to assist in characterizing the pre-Tertiary geology in that area. The primary purpose was to refine the character, thickness, and lateral extent of pre Tertiary confining units. In particular, a major goal has been to define the upper clastic confining unit (late Devonian Mississippian-age siliciclastic rocks assigned to the Eleana Formation and Chainman Shale) in the Yucca Flat area. The MT and AMT data have been released in separate USGS Open File Reports. The Nevada Test Site magnetotelluric data interpretation presented in this report includes the results of detailed two-dimensional (2 D) resistivity modeling for each profile (including alternative interpretations) and gross inferences on the three dimensional (3 D) character of the geology beneath each station. The character, thickness, and lateral extent of the Chainman Shale and Eleana Formation that comprise the Upper Clastic Confining Unit are generally well determined in the upper 5 km. Inferences can be made regarding the presence of the Lower Clastic Confining Unit at depths below 5 km. Large fault structures such as the CP Thrust fault, the Carpetbag fault, and the Yucca fault that cross Yucca Flat are also discernable as are other smaller faults. The subsurface electrical resistivity distribution and inferred geologic structures determined by this investigation should help constrain the hydrostratigraphic framework model that is under development.

Theodore H. Asch, Brian D. Rodriguez; Jay A. Sampson; Erin L. Wallin; and Jackie M. Williams.

2006-09-18T23:59:59.000Z

403

INCREASING OIL RECOVERY THROUGH ADVANCED REPROCESSING OF 3D SEISMIC, GRANT CANYON AND BACON FLAT FIELDS, NYE COUNTY, NEVADA  

SciTech Connect (OSTI)

Makoil, Inc., of Orange, California, with the support of the U.S. Department of Energy has reprocessed and reinterpreted the 3D seismic survey of the Grant Canyon area, Railroad Valley, Nye County, Nevada. The project was supported by Dept. of Energy Grant DE-FG26-00BC15257. The Grant Canyon survey covers an area of 11 square miles, and includes Grant Canyon and Bacon Flat oil fields. These fields have produced over 20 million barrels of oil since 1981, from debris slides of Devonian rocks that are beneath 3,500 to 5,000 ft of Tertiary syntectonic deposits that fill the basin of Railroad Valley. High-angle and low-angle normal faults complicate the trap geometry of the fields, and there is great variability in the acoustic characteristics of the overlying valley fill. These factors combine to create an area that is challenging to interpret from seismic reflection data. A 3D seismic survey acquired in 1992-93 by the operator of the fields has been used to identify development and wildcat locations with mixed success. Makoil believed that improved techniques of processing seismic data and additional well control could enhance the interpretation enough to improve the chances of success in the survey area. The project involved the acquisition of hardware and software for survey interpretation, survey reprocessing, and reinterpretation of the survey. SeisX, published by Paradigm Geophysical Ltd., was chosen as the interpretation software, and it was installed on a Dell Precision 610 computer work station with the Windows NT operating system. The hardware and software were selected based on cost, possible addition of compatible modeling software in the future, and the experience of consulting geophysicists in the Billings area. Installation of the software and integration of the hardware into the local office network was difficult at times but was accomplished with some technical support from Paradigm and Hewlett Packard, manufacturer of some of the network equipment. A number of improvements in the processing of the survey were made compared to the original work. Pre-stack migration was employed, and some errors in muting in the original processing were found and corrected. In addition, improvements in computer hardware allowed interactive monitoring of the processing steps, so that parameters could be adjusted before completion of each step. The reprocessed survey was then loaded into SeisX, v. 3.5, for interpretation work. Interpretation was done on 2, 21-inch monitors connected to the work station. SeisX was prone to crashing, but little work was lost because of this. The program was developed for use under the Unix operating system, and some aspects of the design of the user interface betray that heritage. For example, printing is a 2-stage operation that involves creation of a graphic file using SeisX and printing the file with printer utility software. Because of problems inherent in using graphics files with different software, a significant amount of trial and error is introduced in getting printed output. Most of the interpretation work was done using vertical profiles. The interpretation tools used with time slices are limited and hard to use, but a number to tools and techniques are available to use with vertical profiles. Although this project encountered a number of delays and difficulties, some unavoidable and some self-inflicted, the result is an improved 3D survey and greater confidence in the interpretation. The experiences described in this report will be useful to those that are embarking on a 3D seismic interpretation project.

Eric H. Johnson; Don E. French

2001-06-01T23:59:59.000Z

404

Leveraging Regional Exploration to Develop Geologic Framework for CO2 Storage in Deep Formations in Midwestern United States  

SciTech Connect (OSTI)

Obtaining subsurface data for developing a regional framework for geologic storage of CO{sub 2} can require drilling and characterization in a large number of deep wells, especially in areas with limited pre-existing data. One approach for achieving this objective, without the prohibitive costs of drilling costly standalone test wells, is to collaborate with the oil and gas drilling efforts in a piggyback approach that can provide substantial cost savings and help fill data gaps in areas that may not otherwise get characterized. This leveraging with oil/gas drilling also mitigates some of the risk involved in standalone wells. This collaborative approach has been used for characterizing in a number of locations in the midwestern USA between 2005 and 2009 with funding from U.S. Department of Energy's National Energy Technology Laboratory (DOE award: DE-FC26-05NT42434) and in-kind contributions from a number of oil and gas operators. The results are presented in this final technical report. In addition to data collected under current award, selected data from related projects such as the Midwestern Regional Carbon Sequestration Partnership (MRCSP), the Ohio River Valley CO{sub 2} storage project at and near the Mountaineer Plant, and the drilling of the Ohio Stratigraphic well in Eastern Ohio are discussed and used in the report. Data from this effort are also being incorporated into the MRCSP geologic mapping. The project activities were organized into tracking and evaluation of characterization opportunities; participation in the incremental drilling, basic and advanced logging in selected wells; and data analysis and reporting. Although a large number of opportunities were identified and evaluated, only a small subset was carried into the field stage. Typical selection factors included reaching an acceptable agreement with the operator, drilling and logging risks, and extent of pre-existing data near the candidate wells. The region of study is primarily along the Ohio River Valley corridor in the Appalachian Basin, which underlies large concentrations of CO{sub 2} emission sources. In addition, some wells in the Michigan basin are included. Assessment of the geologic and petrophysical properties of zones of interest has been conducted. Although a large number of formations have been evaluated across the geologic column, the primary focus has been on evaluating the Cambrian sandstones (Mt. Simon, Rose Run, Kerbel) and carbonates layers (Knox Dolomite) as well as on the Silurian-Devonian carbonates (Bass Island, Salina) and sandstones (Clinton, Oriskany, Berea). Factors controlling the development of porosity and permeability, such as the depositional setting have been explored. In northern Michigan the Bass Islands Dolomite appears to have favorable reservoir development. In west central Michigan the St. Peter sandstone exhibits excellent porosity in the Hart and Feuring well and looks promising. In Southeastern Kentucky in the Appalachian Basin, the Batten and Baird well provided valuable data on sequestration potential in organic shales through adsorption. In central and eastern Ohio and western West Virginia, the majority of the wells provided an insight to the complex geologic framework of the relatively little known Precambrian through Silurian potential injection targets. Although valuable data was acquired and a number of critical data gaps were filled through this effort, there are still many challenges ahead and questions that need answered. The lateral extent to which favorable potential injection conditions exist in most reservoirs is still generally uncertain. The prolongation of the characterization of regional geologic framework through partnership would continue to build confidence and greatly benefit the overall CO{sub 2} sequestration effort.

Neeraj Gupta

2009-09-30T23:59:59.000Z

405

An Assessment of Geological Carbon Storage Options in the Illinois Basin: Validation Phase  

SciTech Connect (OSTI)

The Midwest Geological Sequestration Consortium (MGSC) assessed the options for geological carbon dioxide (CO{sub 2}) storage in the 155,400 km{sup 2} (60,000 mi{sup 2}) Illinois Basin, which underlies most of Illinois, western Indiana, and western Kentucky. The region has annual CO{sub 2} emissions of about 265 million metric tonnes (292 million tons), primarily from 122 coal-fired electric generation facilities, some of which burn almost 4.5 million tonnes (5 million tons) of coal per year (U.S. Department of Energy, 2010). Validation Phase (Phase II) field tests gathered pilot data to update the Characterization Phase (Phase I) assessment of options for capture, transportation, and storage of CO{sub 2} emissions in three geological sink types: coal seams, oil fields, and saline reservoirs. Four small-scale field tests were conducted to determine the properties of rock units that control injectivity of CO{sub 2}, assess the total storage resources, examine the security of the overlying rock units that act as seals for the reservoirs, and develop ways to control and measure the safety of injection and storage processes. The MGSC designed field test operational plans for pilot sites based on the site screening process, MVA program needs, the selection of equipment related to CO{sub 2} injection, and design of a data acquisition system. Reservoir modeling, computational simulations, and statistical methods assessed and interpreted data gathered from the field tests. Monitoring, Verification, and Accounting (MVA) programs were established to detect leakage of injected CO{sub 2} and ensure public safety. Public outreach and education remained an important part of the project; meetings and presentations informed public and private regional stakeholders of the results and findings. A miscible (liquid) CO{sub 2} flood pilot project was conducted in the Clore Formation sandstone (Mississippian System, Chesterian Series) at Mumford Hills Field in Posey County, southwestern Indiana, and an immiscible CO{sub 2} flood pilot was conducted in the Jackson sandstone (Mississippian System Big Clifty Sandstone Member) at the Sugar Creek Field in Hopkins County, western Kentucky. Up to 12% incremental oil recovery was estimated based on these pilots. A CO{sub 2} huff ??n?? puff (HNP) pilot project was conducted in the Cypress Sandstone in the Loudon Field. This pilot was designed to measure and record data that could be used to calibrate a reservoir simulation model. A pilot project at the Tanquary Farms site in Wabash County, southeastern Illinois, tested the potential storage of CO{sub 2} in the Springfield Coal Member of the Carbondale Formation (Pennsylvanian System), in order to gauge the potential for large-scale CO{sub 2} storage and/or enhanced coal bed methane recovery from Illinois Basin coal beds. The pilot results from all four sites showed that CO{sub 2} could be injected into the subsurface without adversely affecting groundwater. Additionally, hydrocarbon production was enhanced, giving further evidence that CO{sub 2} storage in oil reservoirs and coal beds offers an economic advantage. Results from the MVA program at each site indicated that injected CO{sub 2} did not leave the injection zone. Topical reports were completed on the Middle and Late Devonian New Albany Shale and Basin CO{sub 2} emissions. The efficacy of the New Albany Shale as a storage sink could be substantial if low injectivity concerns can be alleviated. CO{sub 2} emissions in the Illinois Basin were projected to be dominated by coal-fired power plants.

Robert Finley

2012-12-01T23:59:59.000Z

406

USING RECENT ADVANCES IN 2D SEISMIC TECHNOLOGY AND SURFACE GEOCHEMISTRY TO ECONOMICALLY REDEVELOP A SHALLOW SHELF CARBONATE RESERVOIR: VERNON FIELD, ISABELLA COUNTY, MI  

SciTech Connect (OSTI)

One of the main objectives of this demonstration project is to test surface geochemical techniques for detecting trace amounts of light hydrocarbons in pore gases as a means of reducing risk in hydrocarbon exploration and production. As part of the project, several field demonstrations were undertaken to assess the validity and usefulness of the microbial surface geochemical technique. The important observations from each of these field demonstrations are briefly reviewed in this annual report. These demonstrations have been successful in identifying the presence or lack of hydrocarbons in the subsurface and can be summarized as follows: (1) The surface geochemistry data showed a fair-to-good microbial anomaly that may indicate the presence of a fault or stratigraphic facies change across the drilling path of the State Springdale & O'Driscoll No.16-16 horizontal demonstration well in Manistee County, Michigan. The well was put on production in December 2003. To date, the well is flowing nearly 100 barrels of liquid hydrocarbons per day plus gas, which is a good well in Michigan. Reserves have not been established yet. Two successful follow-up horizontal wells have also been drilled in the Springdale area. Additional geochemistry data will be collected in the Springdale area in 2004. (2) The surface geochemistry sampling in the Bear Lake demonstration site in Manistee County, Michigan was updated after the prospect was confirmed and production begun; the original subsurface and seismic interpretation used to guide the location of the geochemical survey for the Charlich Fauble re-entry was different than the interpretation used by the operator who ultimately drilled the well. As expected, the anomaly appears to be diminishing as the positive (apical) microbial anomaly is replaced by a negative (edge) anomaly, probably due to the pressure draw-down in the reservoir. (3) The geochemical sampling program over the Vernon Field, Isabella County, Michigan is now interpreted as a large negative anomaly associated with the entire field. The results of the State Smock horizontal well and the Bowers 4-25 well confirmed the lack of additional recoverable hydrocarbons in the Vernon Field. (4) The surface geochemistry data showed a strong anomaly in the Myrtle Beach, Burke County, North Dakota area that would justify drilling by itself and even more so in conjunction with the structural interpretation from the geological and geophysical data; the microbial values here were the highest we have observed. The Myrtle Beach geochemical survey indicated a good to excellent prospect which was confirmed by drilling, however, a pipeline has not yet been completed that would allow the wells to be placed into production. We also present in this annual report the results of recent efforts to map carbonate facies tracts in the middle Devonian Dundee and Rogers City Limestones using gamma ray, bulk density, and photoelectric effect geophysical well log amplitudes. This work was undertaken to identify fairways for exploration in the Dundee and Rogers City where surface geochemical techniques could then be used to screen potential leads.

James R. Wood; A. Wylie; W. Quinlan

2004-04-01T23:59:59.000Z

407

MAJOR OIL PLAYS IN UTAH AND VICINITY  

SciTech Connect (OSTI)

Utah oil fields have produced a total of 1.2 billion barrels (191 million m{sup 3}). However, the 15 million barrels (2.4 million m{sup 3}) of production in 2000 was the lowest level in over 40 years and continued the steady decline that began in the mid-1980s. The Utah Geological Survey believes this trend can be reversed by providing play portfolios for the major oil producing provinces (Paradox Basin, Uinta Basin, and thrust belt) in Utah and adjacent areas in Colorado and Wyoming. Oil plays are geographic areas with petroleum potential caused by favorable combinations of source rock, migration paths, reservoir rock characteristics, and other factors. The play portfolios will include: descriptions and maps of the major oil plays by reservoir; production and reservoir data; case-study field evaluations; summaries of the state-of-the-art drilling, completion, and secondary/tertiary techniques for each play; locations of major oil pipelines; descriptions of reservoir outcrop analogs; and identification and discussion of land use constraints. All play maps, reports, databases, and so forth, produced for the project will be published in interactive, menu-driven digital (web-based and compact disc) and hard-copy formats. This report covers research activities for the first quarter of the first project year (July 1 through September 30, 2002). This work included producing general descriptions of Utah's major petroleum provinces, gathering field data, and analyzing best practices in the Utah Wyoming thrust belt. Major Utah oil reservoirs and/or source rocks are found in Devonian through Permian, Jurassic, Cretaceous, and Tertiary rocks. Stratigraphic traps include carbonate buildups and fluvial-deltaic pinchouts, and structural traps include basement-involved and detached faulted anticlines. Best practices used in Utah's oil fields consist of waterflood, carbon-dioxide flood, gas-injection, and horizontal drilling programs. Nitrogen injection and horizontal drilling programs have been successfully employed to enhance oil production from the Jurassic Nugget Sandstone (the major thrust belt oil-producing reservoir) in Wyoming's Painter Reservoir and Ryckman Creek fields. At Painter Reservoir field a tertiary, miscible nitrogen-injection program is being conducted to raise the reservoir pressure to miscible conditions. Supplemented with water injection, the ultimate recovery will be 113 million bbls (18 million m{sup 3}) of oil (a 68 percent recovery factor over a 60-year period). The Nugget reservoir has significant heterogeneity due to both depositional facies and structural effects. These characteristics create ideal targets for horizontal wells and horizontal laterals drilled from existing vertical wells. Horizontal drilling programs were conducted in both Painter Reservoir and Ryckman Creek fields to encounter potential undrained compartments and increase the overall field recovery by 0.5 to 1.5 percent per horizontal wellbore. Technology transfer activities consisted of exhibiting a booth display of project materials at the Rocky Mountain Section meeting of the American Association of Petroleum Geologists, a technical presentation to the Wyoming State Geological Survey, and two publications. A project home page was set up on the Utah Geological Survey Internet web site.

Thomas C. Chidsey, Jr.

2003-01-01T23:59:59.000Z