AndreaBozzo/ceres-open-data-index huggingface dataset:
Development of Methods for Controlling Premature Oxygen Breakthrough During Fire flooding

The overall objective of this study was to characterize the reservoir mechanisms that cause premature oxygen breakthrough, and develop practical tools for controlling it. We did not expect to develop a universal solution, or a solution for each specific mechanism. The focus was on those conditions most likely to be encountered in moderate-depth to deep reservoirs; candidates included gas override, high-permeability steaks, and water underlie. Mitigation measures were selected based on due consideration of the cost of implementing them and their potential application to a wide range of specific problems. An overriding consideration was practicality for field use. The total program was to extend over a 3-year period. It was divided into three phases to permit assessments of completed efforts before proceeding with dependent activities, and to simplify the allocation of funds. ? Phase I consisted primarily of characterizing the problem and selecting candidate mitigating measures suitable for simulation testing and modeling. Some of the design fabrication efforts that could be performed in parallel were also to be included. ? Phase II was to consist of completing the simulator test installation, selecting and modifying the computer model, and then performing the testing and modeling to simulate breakthrough and mitigation in moderate-depth (low-pressure) reservoirs. ? Phase III was to consist primarily of the testing and modeling associated with simulating breakthrough and mitigation in deep (high-pressure) reservoirs.

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DRAWDOWN BEHAVIOR OF GRAVITY DRAINAGE WELLS SUPRI TR 97

An analytical solution for drawdown in gravity drainage wells is developed. The free surface flow is viewed as incompressible, and anisotropy effects are included. The well is a line source well, and the reservoir is infinitely large. The model is valid for small draw downs. The uniform wellbore potential inner boundary condition is modeled using the proper Green's function. The discontinuity at the wellbore is solved by introducing a finite skin radius, and the formulation produces a seepage face. The calculated wellbore flux distribution and wellbore pressures are in fair agreement with results obtained using a numerical gravity drainage simulator. Three distinct flow periods are observed. The wellbore storage period is caused by the moving liquid level, and the duration is short. During the long intermediate flow period, the wellbore pressure is nearly constant. In this period the free surface moves downwards, and the liquid is produced mainly by vertical drainage. At long times the semi log straight line appears. The confined liquid solutions by Theis (1935) and van Everdingen and Hurst (1949) may be used during the pseudoradial flow period if the flowrate is low. New type curves are presented that yield both vertical and horizontal permeability's.

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COMPUTER MODELING OF A THREE-DIMENSIONAL STEAM INJECTION EXPERIMENT

The experimental results and CT scans obtained during a steam-flooding experiment with the SUPRI 3-D steam injection laboratory model are compared with the results obtained from a numerical simulator for the same experiment. Simulation studies were carried out using the STARS (Steam and Additives Reservoir Simulator) compositional simulator. The saturation and temperature distributions obtained and heat loss rates measured in the experimental model at different stages of steam-flooding were compared with those calculated from the numerical simulator. There is a fairly good agreement between the experimental results and the simulator output. However, the experimental scans show a greater degree of gravity override than that obtained with the simulator for the same heat-loss rates. Symmetric sides of the experimental 5-spot show asymmetric heat-loss rates contrary to theory and simulator results. Some utility programs have been written for extracting, processing and outputting the required grid data from the STARS simulator. These are general in nature and can be useful for other STARS users.

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THERMOCHEMISTRY AND THERMOPHYSICAL PROPERTIES OF ORGANIC NITROGEN-AND DIHETEROATOM-CONTAINING COMPOUNDS

This status report provides a summary of research performed by the NIPER Thermodynamics Research Group as part of the Advanced Process Technology (APT) program sponsored by the U.S. Department of Energy Office of Fossil Energy. Included are summaries of data acquired, a discussion of the utility of the data, and an updated assessment for future work.

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PROJECT RIO BLANCO RESERVOIR REPORT

In August 1969, Equity Oil Company engaged CER Geonuclear Corporation to evaluate the prospects for nuclear stimulation of natural gas production in a portion of the Piceance Basin, Colorado. The study area included a block of about nine townships as shown in Figure 1.  In April 1970 a Feasibility Study( 1) was issued for Project Rio Blanco as a result of the work done for Equity Oil Company. The resource evaluation narrowed the study down to a detailed examination of the Fort Union Formation and the Upper portion of the Mesaverde Formation, designated as "Mesaverde 1. " As recommended in the Feasibility Study, two wells, Fawn Creek Government Number 1 and Standard Draw Number 1 were selected for recompletion and testing to obtain more detailed information on the reservoir characteristics. In addition to the testing, several logs were run in the wells. Surface studies of the sand outcrop to determine orientation and extent of sand lenses in the Mesaverde and Fort Union formations were made and seismic surveys were run to determine the location of any geologic discontinuities in the area of interest. This report covers the well testing and recompletion histories on both wells, the evaluation of net gas sand based on the new logs, a report of the outcrop study performed during the summer of 1970, and the seismic survey report from. Seismograph Service Corporation.

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Primary Stratigraphic Traps in Sandstones

Primary stragraphic traps in sandstone in-valve lateral termination of the reservoir as a direct or indirect result of factors related to the depositional environment. Red Wash, Coalinga East, Pembina, Mistsue, Bell Creek, Cut Bank, Burbank, and Bradford are among the very few giant oil accumulations found in such traps. As these traps rarely can be detected by surface measurements, other discovery methods are essential. The understanding f depositional process and environment is a promising approach.

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Uppermost Cretaceous and Tertiary Stratigraphy of Fossil Basin, Southwestern Wyoming

More than 7,000 feet of uppermost Cretaceous and Tertiary continental strata in the northern Fossil basin, along the southern part of the western Wyoming thrust belt, is here subdivided into newly defined formal and informal rock-stratigraphic units. Recognition of these units makes possible the dating of some thrust-fault movement of the development of the Fossil structural basin, and of some later block faulting, as well as reinterpretations of the origins of the strata. The Evanston Formation, which is more than 2,000 feet tick and more extensive in the Fossil basin than formerly recognized, consists of an unnamed lower member, the Hams Fork Conglomerate Member, and the main body. The lower member consists of as much as 500 feet of gray to dark-gray mudstone, siltstone, claystone, and carbonaceous fine-grained, but partially gritty and conglomerate, sandstone and is of latest Cretaceous, probably Lance, age. The Hams Fork Conglomerate Member, previously unmapped erroneously as the Atly Formation along the east side of the Fossil basin, consists mainly of 450-1,000 feet of Intest Cretaceous (Lance) boulder conglomerate and interstratified partly conglomeratic brown and gray sandstone and gray partly carbonaceous mudstone; sources of the well-rounded boulders and pebbles were the nearby upper Paleozoic and Mesozoic formation and lower Paleozoic units of the Paris thrust sheet in Idaho. The main body of the Evanston, 400 to more than 1,400 feet thick, consists mainly of Paleocene but also latest Cretaceous light to dark-gray carbonaceous sandy to clayey partly quartzitic siltstone, gray, tan, yellow, and brown sandstone and conglomerate, carbonaceous to lignitic claystone, ironstone, lignite, and, locally, thin beds of coal.

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Project Rio Blanco Feasibility Study Pieance Basin, Colorado

The prospects for nuclear explosion stimulation of gas production in a portion of the Piceance Basin of Colorado have been evaluated for Equity Oil Company. Data from 38 wells were analyzed to determine: 1 . The optimum areas. 2 . The amount of gas in place amenable to production stimulation in these areas. 3. The most desirable stratigraphic section. 4. The average reservoir rock and fluid properties .  The generally favorable areas containing more than 40 billion standard cubic feet (BSCF) per section were delineated. These two areas comprise approximately 69 sections in the northern portion of the study area and approximately 25 sections in the southern portion. Total gas in place in the most desirable stratigraphic section of these two areas is estimated to be 4. 5 trillion cu ft, based upon log and core analyses using a S% porosity and 70% water saturation cutoff. Maximum gas in place was calculated to be 100 BSCF per section. The Ft. Union Formation and upper portion of the Mesaverde Formation, Mesaverde I, with a combined thickness of about 2,000 ft were found to provide the most desirable stratigraphic section. These intervals consist of alternating layers of shale and sandstone with a typical sandstone/ shale ratio of approximately O. 30. Depths to the section's midpoint vary between 4, 700 and 7, 600 ft in the study area. The median porosity and water saturation of the Ft. Union as calculated from logs were 13. S% and 60%, respectively. Medians for the underlying Mesaverde were found to be 10.5% and 60%. Permeabilities of 0.02 and 0.1 rnillidarcy (md) were calculated for the Mesaverde I and the Ft. Union, respectively, by use of an empirical equation and assuming the calculated median water saturation to be the irreducible water saturation at the calculated median porosity. Since permeability to gas is a critical factor in determining the nuclear stimulation potential, it is recommended that at least two wells be reentered and tested to establish valid in- situ gas permeabilities. These e tests should also be used to qualitatively evaluate reservoir continuity in light of the apparently discontinuous nature of individual sandstone lenses.

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DETERMINATION OF THE OPTIMUM  MASSIVE HYDRAULIC FRACTURING DESIGN FOR THE STIMULATION OF THE WASATCH AND MESAVERDE FORMATION

The MHF project in the Natural Buttes Unit, Bitter Creek Field, Utah has progressed through five of the eight phases of the scheduled program. The last three phases of the program are in progress. Two of the three remaining phases should be finished by 10-1-78, with the testing of CIGE 21-15-10-22 to continue until approximately 1-1-79. Results from this project indicate that IMF stimulations of low permeability sands such as the Slesa Verze-Wasatch are economically high risk. The technology necessary to perform an MHF is adequate, however the results anticipated must be carefully evaluated with respect to economics.

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DEVELOPMENT OF A CHEMICAL FLOODING EOR LITERATURE DATABASE SYSTEM

The volume of information on research on surfactant systems is fairly significant. To identify key areas of research that will need attention, the development of a database system was begun in FY92. The ultimate goal of this work is to develop a system to identify surfactants, or combinations of surfactants, that can be applied to targeted reservoir conditions. The overall system derives information from the literature as well as ongoing research in this area. The capability to identify structure-performance correlations from the multitude of combination of surfactant types and structures that can be used in these formulations will be extremely helpful. The identification of chemical systems that strike a balance between cost and effectiveness will be critical in determining targeted applications of surfactant technology. This status report summarizes the present form of the surfactant database system.

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HISTORY OF MESAVERDE DEVELOPEMENT IN THE SAN JUAN BASIN

The Mesaverde group has probably furnished energy to the regional indicated tribes for several hundred years; oil production was established in 1911 on the Chaco Slope. This paper is a review of the history and producing characteristics of the Mesaverde group within the boundaries of the Blanco Mesaverde pool and the Ignacio-Blanco extension in Colorado. Marketable quantities of gas were first found in 1927 in sec. 29, T. 30 N., R. 9 W., just a short distance from Blanco, New Mexico, from which the pool got its name. The well was drilled by the Huntington Park Oil Company as the No.1 Goede and was dually completed without stimulation in the Pictured Cliffs and Cliff House {formations. A four inch pipeline connected the well to the town of Aztec in 1929. The Pictured Cliffs was produced during the summer and the more prolific Cliff House was produced during the winter. A limited market caused curtailment o{ drilling until the mid-1940's when the California population explosion created a demand for more gas and exploration of the Basin began. When it was determined that sufficient reserves were present an application was made and permission granted to EI Paso Natural Gas Company to build a pipeline to California. This caused extensive drilling and the commercial Mesaverde locations were almost all drilled within the next decade. The Mesaverde group consists of the basal regressive marine sandstone of the Point Lookout formation followed by the non-marine Menefee formation and capped by the transgressive sandstones of the Cliff House formation. Production is primarily from the sandstones of the Cliff House and Point lookout. The reservoir rocks have relatively low porosity and permeability but are fractured. A modern completion will open the fractures and clean up the avenue of escape for the entrapped hydrocarbons.

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Production Strategies for Tight Gas Sands: A Case Study of the Upper Cozzette Blanket Sand

The importance of the role that natural gas from tight formations would play in achieving energy self-sufficiency for the United States cannot be over-emphasized. One reliable commerce estimates the natural gas reserves of the tight sands of he Western United States alone to be more than 57 trillion cubic feet. However, the technology for recovering this resource remains elusive, primarily due to lack of adequate understanding of the physics of fluid flow dynamics within this type of porous media. The fluid flow in tight formations does not subscribe to hat normally associated with conventional reservoirs. It is believed that tight formations frequently possess dual porosity, and the flow field in these formations may be governed by more than one mechanism. The model utilized in this study  possesses woven predictive capabilities, an essential ingredient to production forecasting, and hence is used as a framework for the development of optimal production strategies for the Upper Cozzette blanket sand. The model has multi-well capabilities and has options for either vertically or horizontally fractured wells and horizontal boreholes. Simulation results from a variety of production schemes are presented, The results provide some insight into production strategies involving horizontal boreholes and hydraulic fractures.

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LARAMIDE STRUCTURAL HISTORY OF THE POWDER RIVER BASIN, WYOMING

The Powder River Basin in northeastern Wyoming is asymmetric with its deepest axis along the southwestern side. (Fig. 1 ) . It is Flanked by the Bighorn Mountains, Crisper Arch, Laramie Range, Hartville Uplift, and Black Hills, all formed during the Laramide Orogeny.

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Stratigraphy and Sedimentation of the Paleocene-Eocene Hoback Formation Western Wyoming

In early Tertiary time, the western Wyoming overthrust region underwent several stages of uplift accompanied by synorogenic deposition of thick sediments into subsiding intermontane basins. The Hoback Formation in the Hoback Basin is an example of one of these thick, early Tertiary deposits. The Hoback Formation ranges in age from Middle Paleocene (Torrejonian) to early Eocene (Graybullian). In the center of the Hoback Basin, it is about 16,000 feet thick, but thins southward to about 8,000 feet before plunging into the subsurface in the north end of the Green River Basin, where it intertongues with the Chappo Member of the Wasatch Formation. A conformable, intertonguing and gradational contact separates the Hoback from the overlying Pass Peak Formation, except in a local area along the front of the Gros Ventre Mountains, where the Pass Peak unconformably overlies the Hoback.

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FAULTING ON THE NORTH FLANK OF THE UINTA MOUNTAINS, UTAH AND COLORADO

A complex system of faults forms the boundary between the Uinta Uplift on the south and the several adjacent basins and uplifts which lie to the north and northeast [Fig. 1 ). Four major faults and innumerable associated Faults of lesser magnitude make up this 200 mile-long s).stem. Along the entire mountain flank these faults are high angle reverse or low angle overthrust faults which carry the Uinta Uplift upward and outward, elevating it and causing it to override the margin 01 the adjacent and subjacent basins and lesser uplifts.

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Stratigraphy of the Early Eocene Pass Peak Formation, Central - Western Wyoming

Stratigraphic investigation of the Pass Peak Formation was carried out for a total of seven months in the field during the summers of 1965, 1966, and 1967 in order to provide the necessary framework for interpreting detailed information concerning its provenance, dispersal, depositional environment(s) and tectonic history. The purpose of this paper is to summarize the stratigraphic information gathered in this study.

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Multi-Mechanistic Approach to the Reservoir Analysis of Tight Blanket Sands

Tight sand formations, because of their peculiar characteristics, do not conform to the well established behavioral patterns normally associated with conventional natural gas reservoirs.  These attributes of tight sands render the conventional reservoir models inadequate when applied to tight sands. It is widely projected that gas resources available  in these tight formations, which in the Western United States alone stands at about 5,703 Trillion Cubic Feet, may be the cornerstone of the future energy sufficiency of this country. It is also believed that the major bottleneck in the development of these resources  the lack of understanding of the fluid dynamics in these formations. It is therefore imperative to evolve a good model based on a fundamental understanding of the rather unique physics of flow in this media. A very important unconventional characteristic of tight formations is its dual-porosity nature in the form of micro/macrospore structure and the pressure-field, concentration-field driven flow potentials imposed on the system. This physics calls for the use of dual-porosity, multi-mechanistic approach for the description of the transport of natural gas in these formation. Such a model is presented here. Both synthetic and actual field examples are used to illustrate the predictive capability of the model. Results show that me conventional single-mecharristic approach tends to under-predict recovery, They also demonstrate that the dual-mechanistic approach is of the essence.

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GEOLOGY AND VERTEBRATE PALEONTOLOGY OF THE NORTHEASTERN GREEN RIVER BASIN, WYOMING

Most biostratigraphic work in the Green River Basin has been concentrated in the spectacular middle Eocene outcrops of the southern part of the basin. In recent years, however, more attention has been devoted to studies in the northern part, where much of the exposed rock is somewhat older than that in the south. This paper is a summary of a study concerned with correlation of lower and middle Eocene fluvial and lacustrine sediments at the northern end of the basin. The bases for the relationships projected here are twofold-physical stratigraphy and correlations based on vertebrate paleontology (essentially mammalian) of the units involved.

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Major Ash Constituents in U.S. Coals

Analytical results, including ash fusibility data, are presented by the Bureau of Mines for 10 major constituents in coal ash from 373 samples of commercial US coals. Determinations of SiO2, Al2O3, Fe2O3, and P2O3 were made by colorimetric methods, Na2O and K2O by flame photometry, TiO2, CaO, and MgO by a spectrochemical method, and SO3 by a gravimetric method. In bituminous coal ashes the silicon, aluminum, and iron calculated as oxides often make up about 90% of the ash.

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Performance Characteristics of Coal-Washing Equipment: Dense-Medium Coarse-Coal Vessels

The performance of six dense-medium washers was evaluated in five preparation plants. Three of the plants were making a two-product separation that produced a clean coal and a refuse; one plant employed dense-medium vessels in series to effect a primary and a secondary separations; and one plant was equipped with a two-compartment washer effecting two separations in one vessel. The separate secondary drum-type washer produced a low-ash metallurgical coal and an intermediate-ash product suitable for plant fuel or steam generation. The two-compartment washer produced a premium anthracite product and a middling's product. The sharpness-of-separation values ranged from good to excellent for the five primary separations and for the secondary separation.

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Performance Characteristics of Coal-Washing Equipment: Concentrating Tables

Five preparation plants employing concentrating tables for washing 3/8-inch to 0 raw coal were tested. Two of the plants were washing Pittsburgh-bed coal, two were washing Pocahontas-bed coal, and one was washing Elkhorn-bed coal. Samples of the feed to and products from the tables were collected over the normal operating shift. These samples were analyzed, and complete performance criteria were determined. The results of this study show that the concentrating table is an effective fine-coal cleaner even when operating at 40 percent over the recommended 10 tons per hour feed rate. Recovery efficiencies for the 3/8-inch to 200-mesh size fraction ranged from 97.3 to 99.3 percent; maximum yield errors and ash errors were 2.4 and 1.0 percent, respectively; probable errors ranged from 0.074 to 0.115 specific gravity units and error areas from 52 to 73 square centimeters. The amount of minus 200-mesh material in the water used for feed water and dressing water to the table had no significant effect on the sharpness of the separation achieved but did have an effect on the ash content of the clean-coal product. In the one plant studied, the substitution of fresh water for plant circulating water reduced the ash content of the clean coal by about 6 percentage points.

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