During the year, design, construction and installation of all project equipment was completed, and continuous steam injection began on September 18, 1979 and continued until February 29, 1980. In the five-month period of steam injection, 235,060 barrels of water as steam at an average wellhead pressure of 1199 psig and an average wellhead temperature of 456/sup 0/F were injected into the eight project injection wells. Operation of the project at design temperature and pressure (1000/sup 0/F and 1500 psig) was not possible due to continuing problems with surface equipment. Environmental monitoring at the project site continued during startup and operation.
Computed tomography scans of fractures in small samples of Wolfcamp Shale from the Permian Basin and a depth of approximately 10,400 feet that have been cemented through natural processes. These samples were CT scanned at NETL. The data sets compliment the manuscript by Hajirezaie et al entitled "Mineral characterization of a sealed fracture: A multiscale multimodal imaging study of a syntaxial vein"
DEVONIAN SHALE PRODUCTION AND POTENTIAL
UCR TRS
A map displaying the Shale Plays of North America.
Two methods are used on the Eastern Gas Shales Project to measure the gas volume of encapsulated shale samples. The direct method measures pressure and volume and is initiated almost immediately upon encapsulation of the sample. A second method measures pressure, volume, and composition, and is initiated after pressure is allowed to build up over several weeks. A combination of the two methods has been used on selected samples, and yields more data as it allows extrapolation to account for gas lost prior to encapsulation. The stratigraphic horizons, characterized by dark shales with high organic and high carbon content and a relatively high gamma ray intensity of 200+ API units also have high gas contents (relative to other units within the same well). The Lower Huron, Rhinestreet, and Marcellus Shales are high in gas content relative to other stratigraphic units at the same sites. The difference in gas content of the same stratigraphic horizon between well sites appears to be controlled by the thermal maturity. Kinetic studies have shown that, in some samples, significant amounts of gas are released after the time when the gas volume would be initially measured. Additional work needs to be performed to determine why the rates and volume of gas released vary between samples.
Chen, X., Eichhubl, P., Olson, J. E., 2017, Effect of water on critical and subcritical fracture properties of Woodford shale, Journal of Geophysical Research-Solid Earth, v. 122, 2736-2750. http://dx.doi.org/10.1002/2016JB013708 .
EDX is the Department of Energy (DOE)/Fossil Energy Carbon Management (FECM) virtual library and data laboratory built to find, connect, curate, use and re-use data to advance fossil energy and environmental R&D. Developed and maintained by the National Energy Technology Laboratory (NETL), EDX supports the entire life cycle of data by offering secure, private collaborative workspaces for ongoing research projects until they mature and become catalogued, curated, and published. EDX adheres to DOE Cyber policies as well as domestic and international standards for data curation and citation. This ensures data products pushed public via EDX are afforded a citation for proper accreditation and complies with journal publication requirements.
This report summarizes a multi-year study on the storage stability of synthetic fuels derived from oil shale and coal. A variety of organic nitrogen, sulfur and oxygen compounds were evaluated for their tendencies to promote sediment in hydrocarbon fuels under accelerated storage conditions. Three types of diluents were employed in model compound studies representing fuels of increasing complexity. These were pure n-decane, petroleum-derived jet fuel of the Jet A type, and No.2 diesel fuel. In addition, several middle distillate fuels derived from actual shale liquids were tested and the results compared to the model compound studies. The fuels and fuel mixtures were stored at 110°F (43.3°C) and 150°F (65.5°C) in the dark. Sediment formation was determined gravimetrically. During the course of this work a modified storage stability test was developed which significantly improved the accuracy of sediment determination.
Groundwater data and other chemical data discussing the movement of shales and shale gas in the Marcellus Formation.
This report analyzes water availability across all potentially commercial shale resources worldwide. It also reveals that water availability could limit shale resource development on every continent except Antarctica.
DOE/MC/08216-1331
Hydraulic Fracturing and Associated Stress Modeling for the Eastern Gas Shale Project - Final Report; November 1980
LARGE SCALE FOAM FRACTURING IN THE DEVONIAN SHALE - A FIELD DEMONSTRATION IN WEST VIRGINIA
LITHOLOGIC DESCRIPTION OF CORED WELLS #20402 AND #20403 IN THE DEVONIAN SHALE IN LINCOLN COUNTY, WEST VIRGINIA
A map displaying the Lower 48 States Shale Plays.
Overview of geologic characterization and research and evaluation of geologic carbon storage capacity in the Midwest region.
Maps depicting gas production, shale plays, oil plays, coalbed methane fields, and other data. Maps were developed by GIS software and are in downloadable PDF and JPG format. Maps cover the lower 48 states.
Northwestern Ohio Marcellus Shale Well Locations
From the site: "The Assessment Unit is the fundamental unit used in the National Assessment Project for the assessment of undiscovered oil and gas resources. The Assessment Unit is defined within the context of the higher-level Total Petroleum System. The Assessment Unit is shown here as a geographic boundary interpreted, defined, and mapped by the geologist responsible for the province and incorporates a set of known or postulated oil and (or) gas accumulations sharing similar geologic, geographic, and temporal properties within the Total Petroleum System, such as source rock, timing, migration pathways, trapping mechanism, and hydrocarbon type. The Assessment Unit boundary is defined geologically as the limits of the geologic elements that define the Assessment Unit, such as limits of reservoir rock, geologic structures, source rock, and seal lithologies. The only exceptions to this are Assessment Units that border the Federal-State water boundary. In these cases, the Federal-State water boundary forms part of the Assessment Unit boundary."
From the site: "Cell maps for each oil and gas assessment unit were created by the USGS as a method for illustrating the degree of exploration, type of production, and distribution of production in an assessment unit or province. Each cell represents a quarter-mile square of the land surface, and the cells are coded to represent whether the wells included within the cell are predominantly oil-producing, gas-producing, both oil and gas-producing, dry, or the type of production of the wells located within the cell is unknown. The well information was initially retrieved from the IHS Energy Group, PI/Dwights PLUS Well Data on CD-ROM, which is a proprietary, commercial database containing information for most oil and gas wells in the U.S. Cells were developed as a graphic solution to overcome the problem of displaying proprietary PI/Dwights PLUS Well Data. No proprietary data are displayed or included in the cell maps. The data from PI/Dwights PLUS Well Data were current as of October 2001 when the cell maps were created in 2002."
From the site: "The Assessment Unit is the fundamental unit used in the National Assessment Project for the assessment of undiscovered oil and gas resources. The Assessment Unit is defined within the context of the higher-level Total Petroleum System. The Assessment Unit is shown here as a geographic boundary interpreted, defined, and mapped by the geologist responsible for the province and incorporates a set of known or postulated oil and (or) gas accumulations sharing similar geologic, geographic, and temporal properties within the Total Petroleum System, such as source rock, timing, migration pathways, trapping mechanism, and hydrocarbon type. The Assessment Unit boundary is defined geologically as the limits of the geologic elements that define the Assessment Unit, such as limits of reservoir rock, geologic structures, source rock, and seal lithologies. The only exceptions to this are Assessment Units that border the Federal-State water boundary. In these cases, the Federal-State water boundary forms part of the Assessment Unit boundary."
From the site: "Cell maps for each oil and gas assessment unit were created by the USGS as a method for illustrating the degree of exploration, type of production, and distribution of production in an assessment unit or province. Each cell represents a quarter-mile square of the land surface, and the cells are coded to represent whether the wells included within the cell are predominantly oil-producing, gas-producing, both oil and gas-producing, dry, or the type of production of the wells located within the cell is unknown. The well information was initially retrieved from the IHS Energy Group, PI/Dwights PLUS Well Data on CD-ROM, which is a proprietary, commercial database containing information for most oil and gas wells in the U.S. Cells were developed as a graphic solution to overcome the problem of displaying proprietary PI/Dwights PLUS Well Data. No proprietary data are displayed or included in the cell maps. The data from PI/Dwights PLUS Well Data were current as of October 2001 when the cell maps were created in 2002."
These methods result from about four years of study of shales and recent fine-grained muds. Characterization of shales has been a topic of intensive research under the Eastern Gas Shales Project through a contract study to West Virginia Geological and Economic Survey funded by United States Department of Energy.
Report on the reassesment of storage capacity and EOR potential of Devonian shales in the Appalachian Basin discussing the method of capacity estimation (area, thickness, concentration and density of CO2, storage efficiency factor) and towards demonstration of CO2 sequestration and EOR in shale in the Burk Branch Project wells (Pike County, Kentucky).
Paper discussing the effect/history of Middle–Upper Devonian organic-rich shales on the Appalachian Basin, includes data tables - e.g. data tabulation for Marcellus subgroup study interval.
Shale Basins of the US
The unconventional hydrocarbon resources map of North America provides an overview of major sedimentary basins, plays and active production areas that are targets of gas and liquid extraction. The map has been created from datasets compiled from various sources by the West Virginia GIS Technical Center, Dept. of Geology and Geography, West Virginia University (WVU). This project is a partnership between the National Energy Technology Laboratory (NETL), the US Department of Energy (DOE), and WVU.
Shale Plays in the US
Marcellus and Utica/Point Pleasant shale activity spreadsheets discussing permit amounts are posted weekly at the site.
Double torsion mode-I fracture mechanical properties of three shales under varying water content and aqueous solution chemistry at 23°C and 63°C
Shallow Seismic Investigations of Devonian Shale Gas Production; June 1982
The Tennessee Division of Geology under contract to the Morgantown Energy Technology Center of the U.S. Department of Energy has drilled eight NX core holes in eastern Tennessee. The coring program, under the supervision of R. C. Milici, was designed to retrieve continuous core sections for a detailed characterization study of the Chattanooga Shale. The Geophysical wire-line logging for the NX drill holes was performed by the U.S. Geological Survey.
Resource and reserves estimation methodology for conventional oil and gas reservoirs is based in large part on the historic precedent of geologic and engineering evaluation over the last 150 years. Conversely, the methods used for shale gas reservoirs are recently developed and still evolving. Gas shale formations display complex reservoir characteristics, including free and adsorbed gas, natural fractures, and very low matrix permeability. These characteristics vary significantly vertically and laterally within shale reservoirs, controlled by both depositional setting and subsequent burial and tectonic history. During early stages of a shale gas development program, critical data are required to fully assess the gas in place (resources) and the potential for economic recovery of that gas (reserves). These data, including formation geometry, porosity, organic content and composition, gas sorption, and reservoir pressure, are used by the geologist to begin to understand the static reservoir structure. Stochastic techniques are often employed to populate the static geologic model of the exploration area. Subsequent data obtained from completion and production operations begin to define the dynamic reservoir structure, including completed reservoir volume and flow dynamics. Combining traditional deterministic forecasting techniques (analog, volumetric, decline curve) with more specialized methods (shale gas specific analytic and simulation models) provides an initial understanding of reservoir performance and ultimate recovery. Awareness of the reservoir and reservoir property continuity is critical for assessing with reasonable certainty the extent and viability of this continuous play within and outside of the initial exploration area. Assessing developed plays again relies on a combined stochastic/deterministic approach; however, in this more data-rich setting the geologist will rely on a more deterministic approach for evaluating the changing static and dynamic conditions within the reservoir. From this evaluation, production regions/compartments within the continuous deposit are defined. Production analysis and forecasting at this stage often use a stochastic approach, in part because of the abundant production data and the known variability inherent in shale gas production. Understanding production variability in light of the static and dynamic reservoir conditions can further satisfy the reasonable certainty criteria required for reserves estimation.
A paper discussing the results of a hydraulic fracturing operation. From the paper: "This report describes a large-scale foam fracturing operation performed on a Devonian Shale well in Jackson County, W. Va. Here the Energy Research and Development Administration (ERDA) in cooperation with Consolidated Gas Supply Corp. (CGSC) conducted a foam frac using 973 bbl. water, 2160 MSCF nitrogen, and 155,000 lbs sand proppant. The gross perforated formation interval is 3238-3629 ft. in W. L. Pinnel No. 12041 near Cottageville, Jackson County. The frac test was conducted to help evaluate the effectiveness of foam fracturing in the low-pressure water sensitive Devonian Shale of the Appalachian Basin. The report details the frac job and the well clean-up period with field problems encountered. Also described is the post-frac logging program run to define created vertical fracture extent and gas influx into the well bore. A post-frac deliverability test performed on the well is described."
The intensity of x-rays diffracted from a component of a mixture is proportional to the concentration of that component in the mixture. The proportionality constant is however affected by various parameters including sample preparation and mounting, equipment operation, the composition and crystallinity of the component and the overall composition of the mixture to name just a few. Assuming critical control of sample preparation, mounting and equipment operation, for a specific sample type, weighting factors were determined which when applied to the observed x-ray intensities of the individual minerals allowed a reasonably accurate semiquantitative estimation of the mineral abundances to be calculated. The effectiveness of the weighting factors was evaluated using both parametric and non-parametric statistical comparisons with other conventional analytical procedures. Because the sample preparation and mounting procedures are critical for the success of this or any other analytical technique, the procedures used are detailed.
Generalized geology and profile cross section of area within Appalachian Basin
Map layers associated with the Marcellus Shale in the interactive mapping system include various Onondaga map layers. This is confusing to many users--i.e., why don't we use maps showing the Marcellus structure? The answer is simple--because we don't yet have those specific map layers for the Marcellus Shale. In order to provide this geological information, we are using map layers created for adjacent stratigraphic units to provide approximately similar information as for the Marcellus. Structure Map Layers - The Onondaga Limestone and equivalent units underlie the Marcellus Shale. The top of the Onondaga Limestone and equivalents is approximately equal to the base of the Marcellus Shale. So, a map showing the structure on the top of the Onondaga Limestone provides essentially the same information as a structure map on the base of the Marcellus Shale.
Scanned in two sections. Magnification: x6.74 Optimum voxel size: 29.7 microns (0.001168 inches) Geometric unsharpness: x5.7 5 micron focal spot will be 28.72 micron wide (0.14 pixels)
Geologic and Engineering Analyses and Evaluation of Factors Affecting Widespread Development of Devonian DOE/MC/22140-2651
This data set meets the FAIR data standards required for a public domain repository or general repository. 1. These data are freely available for exploratory analysis 2. If the PI makes a significant intellectual contribution to the research, or if the data are essential to the work, or if an important result or conclusion depends on the data, co−authorship would normally be expected. This should be discussed at an early stage in the work. 3. Manuscripts using the data should be sent to the coauthors for review well before (e.g. 4 weeks) they are submitted for publication, to ensure that the quality and limitations of the data are accurately represented and the coauthors have adequate time to provide input.