AndreaBozzo/ceres-open-data-index huggingface dataset:
Inorganic Geochemistry of Devonian Shales in West Virginia

Cuttings of thirty wells in western and southern West Virginia were analyzed for the major and minor elements: silicon, aluminum, iron, magnesium, potassium, calcium, sodium, titanium, phosphorus, manganese, sulfur, zinc, and strontium. Geographic and stratigraphic trends were studied through statistical methods of factor analysis and trend surface analysis. Trend surfaces showed sulfur decreasing and titanium increasing from west to east, consistent with a model of a delta complex depositing poorly-sorted sediment to the east, and quiet, possibly anoxic marine water over the western part of the study area. In combination with iron, sodium trends suggest that deposition of immature sediments in the southern part of the study area. Silicon percentages are highest in the areas of high titanium percentage, and in black shales of the western margin of the state. The distribution of illite and quartz can be studied through the trend-surfaces for potassium and silicon. Strontium provides little information on the distribution of specific minerals because it can substitute for other elements in several, quantitively important minerals. The distribution of manganese appears to be controlled mainly by the redox potential in the containing sediments. Elemental percentages do not appear to indicate regions of high production potential beyond the correlation of sulfur with black shale. Percentages of sulfur in well cuttings might be used in lieu of petrographic work to measure the presence and quantity of "organic facies."

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Reservoir Heterogeneity Classification System for Characterization and Analysis of Oil Resource Base in Known Reservoirs

The remaining mobile and immobile oil resources occur in a variety of geologic settings and reservoir types. Recovery efficient of hydrocarbons from known reservoirs is largely controlled by internal reservoir architecture and primary and supplemental recovery mechanisms. The internal architecture and character of a reservoir are functions of its genesis. A generally held hypothesis is that reservoirs with similar geological affinities have characteristic production constraints and respond to primary and advanced recovery applications similarly.

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CONTRACTS FOR FIELD PROJECTS AND SUPPORTING RESEARCH ON ENHANCED OIL RECOVERY

The overall objective of this project is to advance current understanding for the successful application of surfactant-enhanced alkaline flooding for tertiary oil recovery. The program is designed to: 1. Study the chemistry of crude oil-surfactant-alkali interactions with respect to both equilibrium and kinetics. 2. Characterize oil-water interfaces for their role in in situ-formed emulsions and in dielectric measurements of saturation in porous media. 3. Study oil bank formation and displacement mechanisms in enhanced oil recovery through in situ generated surfactants augmented by chemical injection by microvideo and microwave absorption techniques. 4. Model alkaline flooding with respect to microscopic processes and simulation of the overall recovery.

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Cross-Borehole Seismic Probing for Petroleum Reservoir Assessment

The 25 joule marine sparker (p-wave source) has been obtained on a three month lease.  The device was tested as received in both a saline and fresh water environment.  Operation (producing a spark) seemed to be more reliable in a saline solution.  Modifications are underway to enable the device to operate in a dry hole.

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Technical Report on Coring Field Operations in the Barrett Resources Corporation MV 8-4

This report describes coring operations in the Barrett Resources MV 8-4 well, SEl4 Sec 4 T7S R96W, Garfield County, Colorado, and presents core descriptions and orientation information. Coring in the well was a cooperative effort between Barrett Resources Company and CER Corporation between November 30 and December 7, 1989, to obtain reservoir data on tight Mesaverde Group sandstones in the Piceance Basin of northwestern Colorado for the U. S. Department of Energy.

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An Assessment of the Oil Resource Base of the United States

A select panel of oil resource analysts, convened on August 31 and September I, 1992 by the Bureau of Economic Geology, The University of Texas at Austin, and the National Institute for Petroleum and Energy Research (NIPER) at the request of the U.s. Department of Energy, concludes that the remaining, recoverable volume of crude oil in the United States ranges from 99 to 204 billion barrels, inclusive of 25 billion barrels of oil carried as proved reserves by the Energy Information Administration (EIA) at the end of 1991 (table A). The range in estimates reflects different assumptions of price and technology (including the geological ability to apply technology). The lower estimate assumes a stable oil price of $20 per barrel (1992 dollars) with existing technology. The higher estimate assumes a price of $27 per barrel (1992 dollars) but 'With advanced technology. The range in. estimates of the remaining resource base recoverable under the given assumptions is equivalent to 35 to 75 years of continued U.s. crude oil production at the current annual rate of 2.7 billion barrels. In the Oil Resources Panel's estimation of recoverable resources, both price and technology are significant and they are almost equivalent in their impact (fig. A). The average estimate for recoverable volumes (total undiscovered resources and reserve growth) at both price levels was approximately two-thirds greater with the assumption of advanced technology than with existing technology (table B).

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Improvement of CO2 Flood Performance

This is the final report of a six-year research project devoted to the study of processes of oil displacement using dense carbon dioxide. The topics studied have included phase behavior and physical properties of mixtures of crude oil with CO2, the phenomena involved in the displacement of oil through reservoir rock under oilfield conditions, the influence of stabilized lamella or C-foam on this displacement and the development of computer programs to simulate the displacement. In addition, the occurrence of no uniformities in the displacement pattern has also been considered. The effect on displacement of permeability heterogeneities in the reservoir have been studied  geostatistically and by direct numerical modeling. Displacement no uniformities that are induced by viscosity and density differences between displaced and displacing fluids have also been considered, and efforts are described for the development of two different types of additive for purposes of mobility control of CO2 floods. One of these is the so-called CO2-foam, formed by simultaneous flow through the formation of dense CO2 with a water solution of a special surfactant. The second type under development in the project is known as direct thickener, and consists of a polymer that is soluble in dense C~ and able to viscosity it. Significant progress is reported on all of the topics mentioned above.

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DOE Coal Liquefaction Baseline Design and System Analysis

The present assignment from PETC is undertaken by Bechtel to develop a computer model for a baseline direct coal liquefaction design based on two stage direct coupled catalytic reactors. Specifically, the scope of work calls for the development of: 1) a baseline design based on previous DOE/PETC results from Wilsonville pilot plant and other engineering evaluations, 2) a cost estimate and economic analysis, and 3) a computer model incorporating the above two steps over a wide range of capacities and select process alternatives.

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DEVELOPMENT OF TECHNIQUES FOR OPTIMIZING SELECTION AND COMPLETION OF WESTERN TIGHT GAS SANDS'PHASE I REPORT

Fluvial sandstone outcrops of the Cretaceous Cedar Mountain and Farrer formations in eastern Utah were studied to determine the geometries and orientations of primary structural elements (trough cross and inclined parallel beds). The channels in these two formations are believed to be physically similar, the former having been exhumed by erosion of adjoining softer sediments. Vector sums of structural element orientations were found to provide acceptable approximations of channel orientations. Average directivity of vector sums for single channel measurement locations were found to be .67 and .25 for the Cedar Mountain and Farrer, respectively. ~median trough width/height ratios are approximately 7. Structural element height distributions are log normal with median values of about .6 and .8 ft. In order to apply the results of this study in the optimization of frac treatments, at/least 20 orientations from each bed are desirable and more than 80 are preferred. Provided that 1) the frac direction can be determined and 2) sufficient orientations can be deduced from logs, it appears that the relationship of channel/fracture-orientations can be predicted. The ability to make this type of prediction was one of the research  goals enumerated at a recent EGR Planning Workshop.

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Two-Dimensional Thermodynamic Model of the In-Situ Underground Coal Gasification Process for the Linked Vertical Well Method in Eastern Thin-Seamed Coals

A preliminary two-dimensional model for in-situ underground coal gasification is presented. The model describes cavity formation from the injection well end during forward gasification, as well as link zone burn up, when the initial link zone geometry is assumed. Cavity growth is predicted via an integral boundary layer analysis with boundary conditions determined by oxygen mass transfer to the wall for forced and natural convection. Preliminary results are based on the complete oxidation of carbon to carbon monoxide and the water-gas reaction, but exclude reaction rate effects. The effect of water influx is discussed and limits to the amount of water which can react with the coal are presented. A comparison of Eastern and Western coals is presented, as well as dimensionless plots which indicate similarity solutions for various blast flow rates.

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FRACTURING FLUID ROCK INTERACTION OF COTTON VALLEY LIME FORMATION

Laboratory analyses were performed on cores taken from Mitchell Energy Corporation (MEC) Muse-Duke Well #1, located in Cotton Valley Lime Formation, Limestone County, Texas, to determine fracturing fluid interaction with the host rock.  Laboratory analyses were performed on cores taken from Mitchell Energy Corporation (MEC) Muse-Duke Well #1, located in Cotton Valley Lime Formation, Limestone County, Texas, to determine fracturing fluid interaction with the host rock. All tests were conducted at simulated in situ conditions of 8800 psi confining pressure, 6400 pore pressure  40% saturation and 285?F. Three candidate fracturing fluids were evaluated: Versagell (Halliburton,1074 ); stratafrac 400 (Dowell,1074 ); Polaris 60 (Western). Tests were carried out to assess, (1) fracturing fluid damage to the rock permeability and (2) clean-up efforts required to return the host rock to its initial permeability. Irrespective of the initial, untreated permeability; post treatment permeability was in the tenths of microdarcies range. Initia1 permeability of the rock treated with Versage11 and Stratafrac 400 was recovered in less than 2 hours. With Polaris 60, post fracture permeability appeared to stabilize at 60 percent of the initial permeability. Further fracturing fluid/rock interaction tests will be performed with the ,above mentioned fracturing fluids on core samples from the same well and microscopic examination of the cores will also be done.

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SURFACTANT-ENHANCED ALKALINE FLOODING FIELD PROJECT

NIPER is beginning a DOE-industry sponsored field pilot test using surfactant-enhanced alkaline flooding technology, which was developed by NIPER. Surfactant-enhanced alkaline flooding is an EOR method that was patented by NIPER in 1989. This near-term application of a promising EOR technology in a fluvial-dominated deltaic type reservoir is consistent with DOE'S oil research strategy and has been given high priority by DOE.

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A Review of Shallow-Shelf Carbonate Reservoirs in the United States

The buried remains of ancient ocean costal regions hold significant amounts of the potentially recoverable oil of the United States. Many of these reservoirs, classed as shallow-shelf carbonates, share a geologic character and producing behavior that should respond to a focused research effort designed to reduce the technical and economic constraints on the recovery of their remaining oil. The U.S. DOE is currently preparing to announce the opportunity for industry to participate with government in a series of research projects to contribute to this goal. This report provides background information regarding DOE's current understanding of the reservoir and geologic characteristics of shallow-shelf carbonates and the principal impediments to increased production from these reservoirs.

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OIL RESEARCH PROGRAM SHALLOW SHELF CARBONATE RESERVOIRS CLASS II

Development of the Geological Classification System Preliminary Grouping of Reservoirs - Classification meetings with Geologic Experts  - strict geologic groupings of reservoirs utilizing geologic principles and statistical criteria Final  Classification System - Decided to use geological considerations exclusively -Validated methodology for describing reservoirs in terms of lithology,  deposition, diagenesis and structural overprint - Balanced the issues of -Meaningfulness: distinct level & types of heterogeneities - Manageability: few enough groupings to serve as classes for the Oil Research Program - Result: 22 Geologic Classes (16 Clastic; 6 Carbonate)

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Western Gas Sands Project

A vital part of the resource assessment and reservoir analysis work in evaluating the potential for gas production from the western basins is the coring program. In addition to the resource assessment, the program should prove valuable in the resource development by providing information needed for gas recovery estimates and well spacing as well as improving stimulation technology. The USGS is doing the majority of the resource assessment work and has the lead role in identifying areas where cores are needed. To obtain the cores, associated well logs, test data, etc., in the areas of interest, the Department of Energy (DOE), or one of its contractors will negotiate cooperative agreements and/or contracts with interested companies. Special well tests and analyses using computer techniques also may be part of the total evaluation program.

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Western Gas Sands Project

This quarterly basin activity report is a summation of the drilling and testing activity in the four primary study areas and the USGS designated core sites of the Western Gas Sands Project (WGSP) (Figure l-1). Pertinent review information for April, May and June 1978, included for each study area, is divided into two sections. The core program section identifies industry activity within the USGS recommended core areas and relates the status of WGSP core acquisition developments. The second part, the activity section, details drilling and testing operations of interest to the WGSP throughout the entire basin or province. Newly staked or completed wells are listed in tabular form. Newly staked wells are shown on a map with yellow numbers and completed wells are shown with red numbers.

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DOE Coal Liquefaction Baseline Design and System Analysis

This report is the Task VI topical report. Task VI concerns the development of an ASPEN process simulation model training manual and presentation of a course on the use of ASPEN and the process simulation model.  The objective of this project is to develop a baseline design and computer simulation model for a  coal liquefaction plant based on two-stage direct coupled catalytic reactor technology used at Wilsonville.

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Characterization of Surfactants in the Presence of Oil for Steam Foam Application

The steam foam process has been applied in the oil fields since the late 19708. The mechanism of the process, however, is not known fully; particularly the detrimental effects of oil on foam, while known, are still unexplained. This hinders field application as the behavior of surfactants cannot be predicted under field conditions. Understanding the mechanisms of foam generation, stability, and mobility of foam to improve the development of field level projects has been the focus of the attention of many workers of the oil industry. Extensive laboratory studies have been carried out, mostly without oil but some with oil. This study falls in the later category. A one dimensional sandpack (6 ft X 2.15 in) model is used to investigate the behavior of four anionic sulfonate surfactants of varying chemical structure with steam. The study is performed with an crude oil at residual oil saturation of about 12 percent of the pore volume. The observed pressure drops across the various sections 01 .he pack are used to study the behavior of the surfactant. The tested surfactants vary in chain length, aromatic structure and number of ionic charges. A linear toluene sulfonate produced the highest strength foam in presence of the oil at residual saturations, as compared to the alpha olefin sulfonates. This is in contrast to the behavior of the surfactants in the absence of oil, where the alpha olefin sulfonates perform better. The reason for this change in behavior is the relative propagation rate of the foams produced by the surfactants. This conclusion is based on the observation that increase in propagation rate decreases the detrimental effect of oil; while the propagation rate is of little significance without oil. The disulfonate performed better in the presence of oil. The improvement in the performance is embedded in the propagation rate of these surfactants as the rate of propagation in this case is also high. But the true mechanism of improvement in the strength of the foam instead of deterioration needs further study.

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Western Gas Sands Project Plan Document FY 1979

The Department of Energy (DOE) has embarked on a program to accelerate the development of domestic energy resources. One project under this program is the Western Gas Sands Project (WGSP) which is directed toward development of new or improved techniques for recovering natural gas from low permeability reservoirs currently not economic. The principal activities that  comprise this project are: Project Management Resource Assessment Research and Development by Energy Research Centers and National Laboratories Field Tests and Demonstrations.

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Geology, Reservoir Engineering and Methane Hydrate Potential of the Walakpa Gas Field, North Slope, Alaska

The goal of the North Slope Hydrate Study is to evaluate the methane hydrate potential of the Walakpa gas field, a shallow gas field located near Barrow, Alaska. Understanding the reservoir potential and predicting the production characteristics of the : Walakpa Fields is accomplished by analysis of the reservoir geology, production test data, as well as field scale geothermal studies.

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Stratigraphic Sections of Jurassic San Rafael Group and Adjacent Rocks in Routt , Park, Pitkin , and Gunnison Counties, Colorado

These sections were measured prior to 1960, before adoption of the metric system. Publication was delayed by other assignments of the authors and later by the untimely death o f J. C. Wright, They are being released at this time because of the increased interest in the uranium potential of Jurassic rocks. The Curtis and Entrada are the only formations of the San Rafael Group that are present in these sections.

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HYDRAULIC FRACTURE BEHAVIOR AT A GEOLOGIC FORMATION INTERFACE: PRE-MINEBACK REPORT

An experiment has been conducted to study hydraulic fracture behavior at a geologic formation interface. Fractures were initiated above and below an interface between welded tuff with modulus of elasticity (E), Poisson's ratio (v), porosity (~) and permeability (k) of 3.B x 106 psi, 0.239, 13% and 0.01 md, respectively, overlying a bedded ash-fall tuff with E, v, ~, and k of 2.4 x 105 psi, 0.312, 45% and 0.01 md, respectively. Nine-thousand gallons and five thousand gallons of colored cement were injected into the ash-fall tuff and welded tuff, respectively, at a flow rate of 6 bbl/min. Conventional fracture design calculations indicated that this volume was sufficient to propagate 50 ft high fractures, 600 ft total length in each zone. Material property measurements from logs and laboratory tests on core samples, in situ stresses in adjacent regions, design calculations, pumping schedules and treatment operations relevant to this experiment are described. Mineback through the experiment regions has been initiated and will allow direct observation of the created fracture systems. Evaluation of the fracture behavior, particularly at the interface, will be performed during mineback and integrated with the present data to provide a better understanding of hydraulic fracturing.

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Activities of the Oil Implementation Task Force

The objective of this year's work is to develop more effective surfactant flooding systems that have broader tolerance to chemical composition in reservoirs. The focus is to mitigate problems that have been shown to have adverse effects on the performance and economics of surfactant flooding processes, to improve the economics of surfactant-enhanced oil recovery through the development of effective oil recovery systems that contain very low concentrations of synthetic surfactants and alkaline additives, and to investigate the application or extension of current chemical flooding technology to near-term problem solving for near-wellbore permeability improvement.

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Degasification Well Bethlehem Mines 32 - 13

In conjunction with the Advanced Energy Systems Division of Westinghouse Electric Corporation and the U.S. Department of Energy, Bethlehem Mines Corporation drilled a well near its Cambria Mine No. 32. The purpose of the well was to predrain gas from coal beds ahead of mining and to vent gob gas subsequent to mining through the well.  The well was drilled, completed, tested and evaluated under the supervision of INTERCOMP. Fiberglass casing was set through all minable coal beds and the principal coal beds were completed and stimulated. Gas flows were measured and evaluated. Gas quality is good with 98.6% methane. Well evaluation showed abnormally low pressures and no water  production. Wellhead shut in pressure of only 26 psig was measured with the bottom completion at a depth of 900 feet. Extended deliverability is predicted to start at 20 Mcfld and decline to 8 Mcf/d over a five year period if the well is produced. The well design and completion procedures demonstrated at this well are significant because they allowed the same well to be used as a gas producer, to be mined through, and to be later used as a gob gas well. The use of the Hydrojet Tool to open the coal zones proved more effective and less expensive then perforating.

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Western Gas Sands Project Plan Document FY 1980

A large resource of natural gas exists in low permeability reservoirs in the western United States that has not been economically producible because of low natural flow rates coupled with increasingly high drilling costs. The Western Gas Sands Project (WGSP) was created in 1977 by the Department of Energy to address this problem. Its purpose is to perform the research, development and demonstration necessary to advance the technology of stimulating natural gas production from these low permeability reservoirs to the point where commercial development by private industry will become possible.

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