AndreaBozzo/ceres-open-data-index huggingface dataset:
Selected mathematical methods for reservoir characterization: state-of-the-art review. Topical report, Project BE1, Task 2

Mathematical and statistical methods currently used in improved descriptions of oil reservoirs are surveyed. These methods are used as follows: (1) to discriminate between strata of different properties, (2) to group strata with similar properties, (3) to calculate effective values for simulator input parameters at a simulator grid bloc scale by using core data (scale-up), and (4) to interpolate between wells for predicting values to be used in the interwell grid blocs. For appropriate use of most of the methods described, more data are needed compared with what is usually available from cored wells. Procedures which include use of well logs and/or nearby outcrop data provide some extra data, based on quantitative understanding of the geological features characteristic to a reservoir. 27 refs., 1 fig.

Tags: Modeling, mathematical model, oil reservoir, statistical model
Selection And Operation Of Deterministic Simulator Project BE1, Task 2, Topical Report; March 1986

A series of simulations was run in an initial study to determine the dependence of critical reservoir parameters, such as residual oil saturation, on reservoir heterogeneities. In the initial work a random set of permeabilities constrained to a log normal distribution was input to a black oil simulator (BEST). At the end of a simulated waterflood, no significant correlation was found between residual oil saturation and permeability. A different approach was then used where a large heterogeneity was placed at the center of the simulation grid. Under these conditions a good correlation between residual oil saturation and permeability was found at the end of the simulated waterflood. In the future, additional simulations will be conducted to determine the minimum resolution required to reflect a reservoir heterogeneity. 1 ref., 8 figs., 2 tabs.

Tags: black oil, reservoir, residual oil saturation
INORGANIC GEOCHEMISTRY OF DEVONIAN SHALES IN SOUTHERN WEST VIRGINIA: GEOGRAPHIC AND STRATIGRAPHIC TRENDS

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.

Tags: DEVONIAN SHALES, Geochemistry, INORGANIC GEOCHEMISTRY, STRATIGRAPHIC TRENDS, Solids
METHANE RECOVERY FROM COALBEDS: A Potential Energy Source

Methane, the primary constituent of natural gas, is often generated during coal-forming processes. Thus, methane is regularly found associated with coals, either as adsorbed gas in the seams or as gas pools in overlying formations. Most of the information on coalbed methane presently available is from mining areas in the eastern U.S., where the coal resource is well defined and mining companies are experienced in dealing with the methane hazard. At present, methane is simply vented from mines; it is estimated that 250 MMe£ of "coal gas" gets vented daily in this country. Very little work ~as been done so far towards utilizing the coalbed methane resource, despite the fact that present day technologies could easily be applied to its production. The U.S. Department of Energy (DOE) Methane Recovery from Coalbeds Project (MRCP) was initiated to encourage the use of this resource, specifically through (1) the delineation and evaluation of the coalbed methane resource to the extent that productive and economically attractive target areas might be reliably chosen and (2) the development of improved, more cost-effective methods, systems, and equipment for economically producing and using methane from both mined and unmined coalbeds.

Tags: Coal Bed Methane, Natural Gas, Resource, coalbed methane, methane
A CRITICAL REVIEW OF THE STATE-OF-THE-ART OF FRACTURE MECHANICS WITH EMPHASIS ON LAYERED ROCKS

This paper presents results of a literature survey of over 70 pertinent
publications and critical reviews of fracture mechanics emphasizing the fracture behavior of layered rocks. Historical perspective, fracture
mechanisms, linear and nonlinear fracture mechanics, energy theories, ductile and brittle fractures, process regions, specific work of fracture, J-integrals, failure theories, static and dynamic fractures, rock fracture mechanics, fracture toughness of layered rocks (e.g., oil shale), experimental and numerical methods are reviewed and discussed. Innovative and premising methods tailored for the fracture mechanics of layered rocks are recommended.

Tags: Geology, Geophysics, Petrophysics, Rock Properties, fractures, layered rocks, oil shale
The mobile phase in coals: Its nature and modes of release: Final report: Part 1, Structural inferences from dry catalytic hydrogenation of a subbituminous coal

In a study to provide insight into the two component structural model of coal and the mechanisms of coal liquefaction, an approach was adopted in which a subbituminous coal was reacted with hydrogen in the presence of an impregnated molybdenum sulphide catalyst and in the absence of solvent. Reactions were conducted at temperatures between 300 and 400/sup 0/C and for reaction times up to 180 min. The composition and yields of gaseous products, chloroform-soluble liquids and insoluble residues were followed as a function of the reaction conditions by means of different analytical and characterization techniques: gas chromatography; /sup 1/H NMR; elemental analysis; FTIR; solvent swelling in pyridine. 105 refs., 20 figs., 12 tabs.

Tags: Coal, Resource, Subbituminous coal, coal liquefaction
CHEM2D: A TWO-DIMENSIONAL, THREE PHASE, NINECOMPONENT CHEMICAL FLOOD SIMULATOR Volume II: CHEM2D Program User's Manual

CHEM2D is a two-dimensional, three-phase, nine-component
finite-difference chemical flood simulator. It can simulate
waterfloods, polymer floods, and micellar/polymer floods using
heterogeneous one- or two-dimensional (areal or cross-sectional)
reservoir models. At present only one injection and four production
wells are available. The user may specify well performance as either
pressure or rate constrained. A constant time step size or a variable
time step size determined by extrapolation of concentration changes may be specified.

Tags: CHEM2D, Chemical flood simulator, Material Engineering Data, Materials, chemical
Project evaluation: Penn Grade Micellar Displacement Project

The Penn Grade Micellar Displacement Project tested the micellar/polymer flooding process in a low permeability portion of the Bradford Third Sand reservoir. This test, herein referred to as the Lawry Test, followed the successful test of the micellar/polymer flooding process in a higher permeability portion of the Bradford Third Sand reservoir (Bingham Test). The Lawry Test failed technically and economically as an oil recovery process. Total oil recovery amounted to about 5.2% of the oil-in-place at the time of micellar injection. Project failure did not appear to be the reusult of poor operational practice. Project participants recognized the difficulty of applying the micellar/polymer process in such a low permeability reservoir at the initiation of the project. Nevertheless, the large reserve of oil trapped within the low permeability portions of the Bradford Field made the project attractive. There appeared to be three major reasons for project failure: (1) reservoir heterogeneity; (2) adverse ion exchange phenomena; and (3) high sulfonate loss. Data from Phase I testing, injection well tracer surveys, injection well logging, produced chloride concentrations and the Phase II evaluation well confirmed that only a small portion of the Lawry pilot was contacted by injected fluids. Produced salinity and hardness levels suggested the occurrence of adverse ion exchange phenomena. Adverse ion exchange behavior would be expected to have resulted in severe sulfonate loss, and low oil recovery. Additional data are needed to confirm this conclusion. In addition, injectivity was low throughout the project. In the absence of the above problems, it is likely that the process would not be practical in areas typical of Lawry because of low injectivity.

Tags: Bradford Third Sand, Geology, Lawry Test, Permeability, Physical Properties, micellar displacement
Survival of MEOR systems in porous media

It was determined that many potential environmental hazards from microbial enhancement of oil recovery (MEOR) technology are extensions of EOR environmental problems. One unique concern of MEOR is that interactions between injected microorganisms and molasses, and those microorganisms already present in the reservoir might pose novel problems. It appeared necessary to obtain information regarding the indigenous microbial flora and the survival characteristics of a MEOR system after it encounters simulated reservoir microbial conditions. We found from laboratory studies that adventitious microbial species present in the molasses overgrew several of the indigenous microorganisms in Berea sandstone cores and also overgrew the injected MEOR microorganisms. From the results of these studies, we conclude that: (1) The introduction of nutrients into a petroleum reservoir could stimulate the growth of indigenous microorganisms. (2) Microorganisms present in injected non-sterile nutrients can overgrow both injected microbes and indigenous microorganisms. (3) Spore-forming bacteria cannot survive time periods in porous media of 4-20 weeks if there are other bacterial types present. 7 refs., 7 figs., 6 tabs.

Tags: Biologic, EOR, ME, Oil, Resource
Adaptation of the black oil simulator to two-phase Status report, Project BE1, Task 4

The development of an unsteady-state procedure for determining three-phase relative permeability curves requires the characterization of the relative permeability curves by adjustable parameters and the adaption of a nonlinear least-squares procedure to the finite-difference approximation of the Buckley-Leverett three-phase flow equation including capillary pressure. A method was developed to represent three-phase relative permeability data by a functional form based on experimental data. Three-phase relative permeability experimental data reported by previous investigators were represented by relative permeability functions. These functions express the relative permeability of a given phase to all fluid saturations (three saturations in the case of three-phase flow) by a six parameter power law equation. The six parameter equations fit the experimental data within 0.53% error. An automatic method also was developed for representing three-phase relative permeability expeimental data. This procedure eliminates errors due to subjective bias. The developed relative permeability functions were incorporated in a multi-dimensional, three-phase black oil simulator. Also, a finite difference Levenberg-Marquardt routine for solving least-squares problems was adapted to the black oil simulator. These modifications make the estimation of the parameters in the relative premeability functions possible by fitting simulated transient three-phase displacement tests to experimental tests. Preliminary results using two-phase flow displacement showed that the parameters can be estimated within a reasonable amount of computer time. Although preliminary results showed that the program works adequately for two-phase flow, conclusions cannot be stated at the present time since some errors were found in the Fortran code of the optimization function. Appropriate changes have been made, and the new version is being tested. 

Tags: Oil, Resource, black oil simulator, permeability
Evaluation of emulsion steam blocking processes. Project OE3B. Annual report for FY 1985

Laboratory work on this project started in late April 1984. During the first year of this project, FY 84, the effectiveness of emulsion blocking at elevated temperatures was demonstrated. Emulsions were identified that could be injected into cores, which reduced permeability up to 95 percent and withstood steam injection. It was found that dilute water-external emulsions were stable in fresh water (condensed steam) and had viscosities low enough for injection. The work in FY 85 demonstrated blocking in cores with residual oil saturation, in situ generation of blocking emulsions, and the examination of surfactant blends that produce macroemulsions spontaneously or at least with minimum input of mechanical energy. This report addresses Tasks 4-8 of project OE3B. The paper, ''Blocking of High Permeability Zones in Steamflooding by Emulsions'' in the Appendix has been processed separately for inclusion in the Energy Data Base. 18 refs., 4 figs., 17 tabs.

Tags: Experimental, cores, emulsion
Sodium bicarbonate in chemical flooding: Part 1: Topical report.

To compare oil recovery and alkali consumption in alkaline flooding using sodium bicarbonate with other alkaline agents, coreflooding experiments were performed in turn with viscosified sodium bicarbonate and viscosified sodium carbonate solutions. Oil recovery was monitored, and the effluent brine from these corefloods was analyzed for silicon, aluminum, pH, and total inorganic carbon. The results indicate that viscosified sodium bicarbonate recovered more of the asphaltic Cerro-Negro crude than of the less asphaltic Wilmington crude oil. The recovery efficiency using the viscosified sodium carbonate was similar for the two crudes. For both crudes, the percent oil recovery using viscosified sodium carbonate was slightly higher than that using the viscosified sodium bicarbonate. Mineral dissolution and decrease in pH were found to be greater in corefloods using viscosified sodium carbonate. Total inorganic carbon recovery can be obtained in corefloods with either agent, provided that a sufficient water drive follows the chemical slug. Long-term experiments were performed by recirculating alkaline solutions through oil-free, unfired Berea sandstone to monitor the rock/alkali interactions. The experimental results indicate an eight-fold decrease in quartz dissolution by sodium bicarbonate compared with sodium carbonate. Moderate magnesium solubility was observed at the pH of the bicarbonate solution. Low solubility of magnesium and aluminum at the pH of the carbonate indicates the possible formation of precipitates. In these experiments 13% of the carbonate was converted to bicarbonate. Total alkalinity was not significantly decreased with either agent. 18 refs., 5 tabs.

Tags: Oil, Resource, coreflooding, oil recovery
New and improved dispersion and recovery techniques for slurry phase catalysis. 1984

A mathematical model has been developed for predicting the effects of various parameters such as recycle rate, permanent and temporary deactivation rate constants on catalyst activity. The intent of this analysis is to evaluate the importance of the ease with which a catalyst can be regenerated and to identify important catalyst properties associated with regeneration. A reactor (hydrotreater)-regenerator system having equal catalyst inventory in each unit is used as a basis for modeling. A fixed amount of fresh catalyst supply and spent catalyst withdrawal are assumed to be applicable to the reactor. The analysis shows that a small percent increase in the permanent deactivation rate constant relative to total deactivation rate constant decreases the mean activity of the catalyst in the reactor significantly. In most cases, the mean activity of the catalyst increased with increasing recycle rate. The effect of regeneration rate constant on the catalyst activity was not significant compared to that of permanent deactivation rate constant. 13 references, 3 figures.

Tags: Modeling, mathematical, slurry phase catalysis
Western Gas Sands Project: abstracts information system

A bibliography containing citations on the technological, geographical, geological, geophysical, geochemical, and environmental aspects of natural gas recovery from tight sands is presented. Dissemination of technical information is a principal goal of the Western Gas Sands Project. A vast amount of information, relevant to western tight gas sands activities, of varying degrees of technical complexity, has been and continues to be published in the technical literature. Recently, as increasing gas prices draw increased private sector attention to previously sub-economic resources, and as results from the Government-sponsored R and D of the last several years become available, the quantity of literature related to the geology of tight gas formations and to diagnostic and production stimulation technology, has sharply accelerated. Efficient expenditure of future R and D funds requires researchers to be familiar with related previous work. Therefore, a data base has been prepared which contains records for journal articles, reports and other documents relevant to western tight gas sands activities.

Tags: Natural Gas, Resource, Tight Gas, Western Gas Sands Project
Seismic evaluation of NOSR 2.

In June 1981, the Department of Energy (DOE) elected to conduct a seismic evaluation of NOSR 2 in Utah. This survey was carried out by TRW for DOE as part of the resource assessment of the Naval Oil Shale Reserves. The objective of the seismic survey was to determine if there are any structures on the Reserve which may have trapped hydrocarbons. An evaluation of the results indicated the elongated anticlinal structure in the southeast corner (Tabyago Dome) does have dip reversal and that there is a closed structure. Centered in Section 21, T13S, R19E, that structure has a high probability of having trapped hydrocarbons. Any well drilled on that structure should test all the potential producing formations down to the Pre-Cambrian (15,000 feet). It is also possible that several stratigraphic traps exist on a north-trending anticline in R19E. The seismic survey was carried out during August-September 1981 when the Seismograph Service Corporation (SSC) shot an additional eight seismic lines over the entire Reserve. With the three existing commercial seismic lines, a total of 66.25 miles of seismic profiles were available for the evaluation. Additional geologic information from existing reports and data from producing areas which surround the Reserve also were used in making the final assessment. 9 references, 7 figures, 3 tables.

Tags: Naval Oil Shale Reserves, Oil, Resource, seismic survey
Western gas sands project status report, August 1-31, 1980

August progress of government-sponsored projects, directed towards increasing gas production from the low permeability gas sands of the western United States, is summarized in this report. Superior Oil has not yet made a decision concerning the use of their lease as a possible MWX site. Bartlesville Energy Technology Center has completed embedment tests of 20/40 mesh bauxite into grey berea and typical tight gas sand cores. At Lawrence Livermore National Laboratory, numerical routines have been developed for computing unsteady growth of hydraulically-driven cracks in plain and circular geometries. Three studies have been initated at Sandia National Laboratories: laboratory determination of the fracture crack-tip process zone; detailed petrographic characterization of a Mesaverde tight gas sand lens and surrounding shale; and determination of oil-base drilling fluid invasion in support of the MWX.

Tags: Natural Gas, Resource, Western gas sands project
Tertiary Oil Recovery Processes at the University of Texas, Final Report, October 1980-December 1984

This report summarizes four years of research jointly funded by
the Department of Energy and by a number of companies all interested in enhanced oil recovery using micellar/polymer processes. The fundemental thrust of the research was to study the influence of surfactant structure on those physical chemical aspects such as oil/water interfacial tensions and adsorption which have an impact on the efficiency of the flooding process. The role of surfactant structure is therefore the unifying theme which links all of the various projects described here. In many cases we perceived the rieed to carry out studies using surfactant systems which were essentially pure. During the middle and latter phases of this project that· part of our research team responsible for the synthesis of pure surfactants developed methods which provided surfactants of high quality. Tests using various techniques (NMR, phase behavior, etc.) were carried out to ensure their quality. This capability contributed greatly to the significance of the results.

Tags: Oil, Resource, tertiary oil recovery
Production Histories of the Piceance and Uinta Basins of Colorado and Utah; November 20, 1980

The Western Gas Sands Project was initiated by the United States Department of Energy in 1977 to investigate the resource of natural gas existing in low permeability reservoirs. The Greater Green River, Piceance and Uinta Basins, and Northern Great Plains Province, containing low permeability, gas bearing formations, were designated as target areas. A geological data base is being generated for the low permeability formations in these target areas from subsurface geological data and from data on producing wells that penetrate these formations. This report summarizes the production histories of the Piceance and Uinta Basins and is intended to accompany the Western Gas Sands Project: Stratigraphy of the Piceance Basin, by Anderson (1980).

Tags: Natural Gas, Resource, Tight Gas, Western gas sands project