AndreaBozzo/ceres-open-data-index huggingface dataset:
INFILL DRILLING MODEL DEVELOPMENT PROJECT

Included in this volume are three reports which document ICF Resources'literature search project that was conducted under the BPO Infill Drilling Model Development Task. The majority of the literature search effort is summarized in these reports, which cover the following topics: Infill Drilling Model Development Project: Literature Search Methodology and Results: This report documents the literature search methodology and summarizes the results of the various searches that were conducted. The report includes detailed bibliographies for over 400 articles which were compiled into 19 topical volumes. Review of Literature for Application in Infill Drilling Model Development: Dykstra-Parsons Coefficient and Reservoir Continuity: This report documents the effort early in the infill drilling development task where attempts were made to establish bounds for values of continuity and Dykstra-Parsons coefficient based on geologic class. The effort was unsuccessful and the report discusses the reasons why and also documents the literature which is available on these two topics. Class IT: The Shallow Shelf Carbonate Reservoirs. Geologic Class Definition and Discussion of Oil Recovery Problems: This report was developed as a prototype class description report. The report defines the geologic characteristics of reservoirs in the shallow shelf carbonate class of reservoirs and summarizes the oil recovery problems which are described in the literature for reservoirs in this class.

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Direct 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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A Review of the Potential for Obtaining Natural Gas from Sub-surface Hydrate Formations

Gas hydrates-are crystalline, ice-like compounds composed of water and natural gas, Until recently their importance to the petroleum and natural gas industries was attributable to the formation of solid gas hydrates in gas pipelines (Hanmerschmidt, 1931). Most studies of hydrates during the last half century have concentrated on experimental measurement and theoretical prediction of the pressure, temperature and composition conditions of hydrate formation (Katz et al, 1959: Dyk and Fornina, 1958; Parrish and Prausnitz, 1972). The discovery of natural gas and oil in colder climatic regions such as Alaska, Canada's Northwest Territory, and Russian Siberia, has renewed interest in gas hydrates because of the possibility that such hydrates contain vast quantities of natural gas.

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PHASE BEHAVIOR AND OIL RECOVERY INVESTIGATIONS USING MIXED AND ALKALINE-ENHANCED SURFACTANT SYSTEMS

The results of an evaluation of different mixed surfactant and alkaline-enhanced surfactant systems for enhanced oil recovery are described. Several mixed surfactant systems have been studied to evaluate their oil recovery potential as well as improved adaptability to different ranges of salinity, divalent ion concentrations, and temperature. Several combinations of screening methods were used to help identify potential chemical formulations and determine conditions where particular chemical systems can be applied. The effects of different parameters on the behavior of the overall surfactant system were also studied. Several commercially available surfactants were tested as primary components in the mixtures used in the study. These surfactants were formulated with different secondary as well as tertiary components, including ethoxylated and non-ethoxylated sulfonates and sulfates. Improved salinity and hardness tolerance was achieved for some of these chemical systems. The salinity tolerance of these systems were found to be dependent on the molecular weight, surfactant type, and concentration of the surfactant components. Oil displacement experiments in Berea sandstone cores showed considerable improvement in oil recovery potential of these mixed and alkaline-enhanced surfactant systems. Research results have shown the existence of favorable conditions for oil recovery using these two methods. Some of these displacement experiments were conducted with the aid of imaging tools such as NIPER's computer-aided tomography (CT) scanner to determine the progression of the flood. The effectiveness of the surfactant formulation and the mobility control system were monitored using this technique. Several reservoirs were selected as the focus of the research for the application of these improved chemical flooding methods. These reservoirs included North Burbank (OK) Unit, Hepler (KS) Field, and the Government Wells (TX) field. The Burbank reservoir was selected from several Class 1 reservoirs. A database evaluation for this reservoir class was conducted. The Burbank reservoir properties were identified as grouped within the mid-range values for this class. North Burbank retains a significant reserve of unproduced oil and has been identified as a prime candidate for the application of advanced chemical EOR methods.

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Assessment of Michigan Basin Shale Characterization Research and Results Task 11-C

The purpose of Task 11-C , Assessment of Michigan Basin Shale Characterization Research and Results, is to review all technical publications and interface with the Principal Investigators concerning the work being performed by DOE'S Laramie Energy Technology Center under contract to Dow Chemical Company and its sub contractors for the resource characterization of the Antrim Shale in the Michigan Basin. As a result of this study, specific recommendations for future Eastern Gas Shale Project (EGSP)-funded work in the Michigan Basin are presented. The discussion of current Michigan Basin activities relates the Antrim Shale studies to the goals and objectives of the EGSP.

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DEVELOPMENT OF A CHEMICAL FLOODING EOR LITERATURE DATABASE SYSTEM

Chemical flooding is a flexible enhanced oil recovery(EOR) method and has the potential of recovering more residual crude oil than other available methods. The capability to adjust an injected chemical formulation for a wide range of reservoir conditions. and crude oil types remains a valid strong point for this technology. It has been identified by the Department of Energy (DOE) as an important oil production technique targeted for Class 1 reservoirs. For many U.S. domestic oil reservoirs, chemical flooding may be the only viable EOR method.

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DOE Coal Liquefaction Base Line 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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THE DEPARTMENT OF ENERGY'S WESTERN GAS SANDS PROJECT MULTI -WELL EXPERIMENT

Department of Energy has initiated a Multiwell  Experiment with the objectives: (1) characterization of low permeability, lenticular gas sands and (2) evaluation of state-of-the-art and developing technology for their production. The location is in the Rulison Field in the Piceance Basin, Garfield County, Colorado where the lenticular Mesaverde sequence and the underlying blanket Corcoran-Cozzette are the formations of interest and lie at depths between 4,000 and 8,600 ft.

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GAS DETECTION IN THE EXTREMELY SHALY BOWDOIN FORMATION OF NORTHERN MONTANA

Improvements in drilling, completion, and stimulation techniques have increased the productivity of many shallow shaly-sand gas reservoirs. The Bowdoin formation in Northern Montana is a good example of this reservoir type. The depositional environment for the Bowdoin formation is placed in deep water in the Upper Cretaceous time period. In the producing interval, the formation consists of a series of thin laminated sandstones, silts, bentonitic shales, and clays. The entire interval can be over 200 feet thick. Core and log indications show the clay content to be near 50 percent in the producing interval. Since the shale content is so high, and the permeability consequently low, it becomes difficult to evaluate this formation by conventional methods.   A resort to empirical methods is suggested. This paper reports the successful use of porosity-overlay methods to predict and achieve commercial scale gas production in over fifty wells in the Bowdoin producing horizon. Sonic-neutron comparisons are used for gas detection, and sonic-density comparisons for determination of shale content. The information gained from these logs is also used to plan completions; a critical factor, since optimum stimulations are essential to profitable operations in formations like the Bowdoin.

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Stratigraphic Measured Sections of the Upper Cretaceous Mancos Shale (Upper Part) and Mesaverde Group (Lower Part), Moffat County, Colorado

Twelve sections of the uppermost part of the Mancos Shale and the lower part of the Mesaverde Group ( I l e s Formation) of Late Cretaceous age have been measured in a linear distance of about 50 m i (83 km) in  northwestern Colorado as part of a study of depositional environments of impermeable ("tight"', <O. 1 md) gas-bearing reservoirs in the Sand Wash basin of the Greater Green River Basin. This study focused on interpretation of facies based on lateral and vertical associations of rock types, textures, sedimentary structures , contact relations , and faunas. The depositional model derived from this study (Kiteley, 1979) indicates that most reservoirs-shallow shelf sand bars, barrier  beaches, delta margin sands, distributaries and fluvial channels-are discontinuous but nevertheless systematic and predictable, and that reservoir quality is related to depositional environment*

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Stratigraphic Sections of Jurassic San Rafael Group and Adjacent Rocks in Delta, Mesa, and Noatrose Counties, Colorado

These sections were measured prior t o 1960, before adoption of the metric system. Publication was delayed by other assignments of the authors and 1 after by the untimely death of J. C. Wright. They are being released at this time because of the increased interest in he uranium potential of Jurassic rocks.

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PARTICLE SIZE DISTRIBUTIONS GENERATED BY CRUSHED PROPPANTS AND THEIR EFFECTS ON FRACTURE CONDUSTIVITY

Department of Energy supported research conducted in the tight gas sands of the Piceance, Uintah, and Green River Basins of Colorado, Utah, and  Wyoming  directed toward evaluating massive hydraulic fracturing (MHF) for increasing natural gas production.  Research at Bartlesville Energy Technology Center supporting the Western Gas Sands Project consists of examining potential areas of formation damage by MHF fluids and proppants. Fractures produced by the MHF process are propped open by placement of particulate materials creating zones of high permeability and porosity. In this research, high permeability fractures were simulated by placing 40/60 mesh sand proppant between core halves, and subjecting the cores to increasing overburden pressure. As the proppant was crushed, the resultant particles were transported through the propped fracture by frac fluids. Mean, mode, and number per unit volume of the produced particle size distributions were pleasured and related to overburden pressure. The effects of particle retention, when pumping similar particle distributions through the propped fracture, were detected by a pressure change across the core. Measured changes in the filtration efficiency, conductivity, and threshold plugging pressure of 'the propped fracture showed significant particle trapping within the porous media. Pressure versus time plots indicate successive pore plugging and particle breakthrough until the fracture is ultimately plugged.

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General Geological and Production Characteristics of Deltaic Reservoirs with Annotated Bibliography

Deltas form where streams transport large quantities of sediment into bodies of water such as lakes, bays, lagoons, or the ocean, creating potential reservoir facies. Depositional facies are three-dimensional rock bodies whose environmental origins can be inferred from the physical characteristics of the rock. Fluvial processes interact with the sediment reworking and redistributing properties of tidal and wave processes to varying degrees resulting in three genetic types of deltas that can be recognized based on sand distribution patterns, particularly delta front sands, and lateral and vertical facies relationships. The general area where an active stream enters the ocean or other body of water is called the delta front. Each of the three major types of deltas affects the distribution of the delta front sands, often the best reservoirs, in different ways. Fluvial-dominated deltas tend to build elongate "fingers" of delta front sands, and the general distribution of major sands tends to be perpendicular to the shoreline. The delta front sands on wave-dominated deltas tend to be reworked into numerous coastal barriers that are oriented roughly parallel to the shoreline. Tide-dominated deltas tend to have sand-choked channels and build tidal sand ridges in the delta front area which are oriented perpendicular to the shoreline.

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Field Evaluations of Reservoir Fracturing

Considerable volumes of natural gas are known to exist in many areas of the western United States, but occur in formations with permeability and porosity too low to permit economic development with current technology. The Department of Energy (DOE) has implemented the Western Gas Sands Project (WGSP) to characterize these areas and formations and their natural gas resources, to develop techniques that will permit their development economically, and to speed commercialization of the resources. The Gas Research Institute (GRI) has instituted their project for field evaluations of reservoir fracturing to further develop the producibility of gas reservoirs in the tight sands by providing field data essential to studies of reservoir fracturing mechanics and natural gas production and to conduct field evaluations of certain advanced technology.

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Reservoir Characterization and Enhanced Oil Recovery Research

The research in this annual report falls into three tasks each dealing with a different aspect of enhanced oil recovery. The first task strives to develop procedures for accurately modeling reservoirs for use as input to numerical simulation flow models. This section describes how we have used a detailed characterization of an outcrop to provide insights into what features are important to fluid flow modeling. The work leads to a discussion of pseudo functions and how they are used in reservoir modeling to capture geologic features, and also to the notion of a test case for measuring the utility of statistical models. The work describes diagnetic patterns which occur in a carbonate outcrop and attempts to explain these from a fluid flow-reaction model. The second task deals with scaling-up and modeling chemical and solvent EOR processes. In a sense this task is the natural extension of task 1 and, in fact, one of the subtasks uses many of the same statistical procedures for insight into the effects of viscous fingering and heterogeneity. Other subtasks use UTCHEM, a compositional chemical flooding numerical model, to estimate reservoir properties from single-well tests, and apply expery system approaches to design chemical and compositional model input. A largely experimental subtask investigates the effects of cation exchange capacity and chromium retention of the polymer gel process. The final task involves surfactants and their interactions with carbon dioxide and reservoir minerals. This research deals primarily with phenomena observed when aqueous surfactant solutions are injected into oil reservoirs. The reason for injecting surfactant solutions is to render the displacement of oil by carbon dioxide a more efficient process. Aqueous surfactant solutions may disrupt the stability of thin aqueous films, characteristic of water-wet rocks, surfactant solutions may adsorb onto the rock, or surfactant solutions may interact with oil to produce microemulsions. All of these effects are detrimental to the efficiency of carbon dioxide mobility control by foams and all are discussed in the final section of this report.

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PRELIMINARY RESULTS OF MITIERALOGY AND PETROLOGY OF THE TOP INTERVAL (DEPTH 4180-4400 f t ) DRILL CORE MTJX-1

Sandia National Laboratories is conducting and directing the Multi- Well Experiment (MWX) core analysis program as part of the Western Gas Sands Project for the Department of Energy's Unconventional Gas Sands Program. Sandia National Laboratories will carry out sample selection , sample distribution , prioritization of analyses, distribution of data , and coordination of interagency analyses. The U.S.G.S., along with Sandia, will provide interpretation of analytical results . A sedimentological model of the Mesaverde Group at the multi-Well site will be published by J . C . Lorenze (Sandia).

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Feasibility Studies of In-Situ Coal Gasification in the Warrior Coal Field

The State of Alabama possesses extensive coal resources, and is a major coal producing state. Although these resources are impressive, there are many thin, deep coal seams which cannot be economically recovered by conventional means. The south-westward dip of the Warrior coal basin into Mississippi results in many coal seams which have a prohibitive amount of overburden for surface or underground mining using conventional technology. In addition, the coal is a swelling bituminous coal , which presents quite different problems in gasification from the lignite and sub-bituminous coals which have constituted the major research effort for in situ gasification in this country. This research was aimed at the development of technology for the underground gasification of these thin, deep seams of swelling bituminous coal.

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Log Analysis in Low-Permeability Gas Sand Sequences- Correcting for Variable Unflushed Gas Saturation

This paper outlines the technology required to correct porosity for variable unflushed gas saturation. Gas effect on density and neutron logs in fundamental to gas detection. However, in mud drilled wells, a mud filtrate invasion front generally advances radially from the borehole walla and displaces gas within a "flushed zone." Peropheral to the flushed zone is an "invaded zone" characterized by less thorough gas displacement, and, therefore, a higher residual gas saturation. Since density and neutron tools have depths of investigation which are somewhat shallow, gas effect is significantly influenced by the depth of invasion and the thoroughness of flushing. The depth of invasion is generally shallow in high porosity reservoirs and deep in lower porosities. Data presented within this paper, however, show that this generally accepted logion axiom is true only up to a certain point. When low porosity tight gas sand reservoirs are at a critical minimum water permeability, no invasion takes place. Above this minimum permeability, both time and differential pressure control invasion profile. The consequence of this phenomenon is that the porosity of a very poor quality gas reservoir is overestimated, water saturation is underestimated, and the producible gas zone does not contrast well with the tight zone. Thus, the goal of log analysis- to discern the better zones for completion is not achieved. An iterative mathematical model, involving the density, neutron, and gamma ray response equations, is developed to solve for "Sxo" which in this vase is actually the average saturation of the zone investigated by the density and neutron tools. This "Sxo" is then used to provide more reliable porosity interpretation. This technique is verified by comparing log calculations to core data. Aside from more reliable porosity, interesting spinoffs of the technique are: 1) a more reliable procedure to interpret gas saturation in uninvaded formations (independent of Rw and Rt,1034 ); 2) a new procedure to interpret Rw in uninvaded formations; and 3) a new system to identify invaded and, hence, producible gas zones.

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Western Gas Sands Library Microfiche

The U.S. presently is faced with a developing crisis in its energy resources and specifically in its supply of record key natural gas. The use of nuclear explosives in the stimulation of low-permeability gas reservoirs has the potential of supplying more than 300 trillion Cu ft of gas, and amount greater than the nation's presently proven gas reserves. Two nuclear-explosive gas-stimulation experiments have produced a substantial quantity of gas. An "economic projection is made of commercial production (after the successful completion of a research and development program) - for nuclear-explosive, stimulation of wells in the Piceance and Green River Basins in Colorado and Wyoming the internal rate of return on investment varies from 7-1/2 to 28 1/2% depending on the properties of the reservoirs and the required number of explosives per well, assuming a wellhead price for gas of 40 centers per thousand cu ft. A schedule is proposed for the commercial development of the rate of 3.4 trillion cu ft by the year 2000.

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Feasibility Study to Modify the DOE Steamflood and Co2 (Miscible) Flood Predictive Models Respectively To Include Light Oil Steamflooding and Immiscible Gas Drive

The Department of Energy (DOE) currently maintains a suite of simplified, predictive computer models for enhanced oil recovery (EOR) processes for use in reservoir EOR screening analysis and economic feasibility calculations. As valuable planning tools, these codes should have as broad a capability as possible. EOR processes which can now be evaluated include heavy oil steam drive, polymer flooding, micellar polymer flooding, in situ combustion, and CO2 miscible flooding. Among the known available EOR processes, light oil steamflooding, steam soak, immiscible gas drive, and microbial EOR (MEOR) have not been addressed by the DOE predictive models. To consider including modeling capability for any of these requires additional knowledge of the ultimate EOR production potential for each process, as well as the technical feasibility of effecting the code improvements necessary. Based on common knowledge of current EOR field practice, MEOR is eliminated from further consideration, since it has not been fully demonstrated at field scale. The DOE has recently received a new cyclic steam stimulation (steam soak) code from Venezuela, therefore this process will also be excluded from consideration. The following sections discuss process EOR potential, necessary code improvement steps, and project manpower and scheduling for including light oil steamf100ding and immiscible gas drive in DOE's predictive models. Inclusion of reservoir dip angle in the CO2 miscible model is also discussed.

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