AndreaBozzo/ceres-open-data-index huggingface dataset:
Development of a Data Management System for Assistance in Conducting Area Of Reviews (AORS) on Class II Injection Wells in Oklahoma

The purpose of this project is to provide the resources and capabilities necessary to permit the State of Oklahoma to conduct Area of Review (AOR) variance analysis on a statewide level. The project allows for the analysis and identification of areas which may qualify for AOR variances, the correlation of information from various databases and automated systems to conduct AORs in area which do not qualify for variances, the evaluation of the risk of pollution, during permitting and monitoring, using risk-based data analysis. and the ability to conduct spatial analysis of injection well data in conjunction with other geographically referenced information.

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EXPERIMENTAL DETERMINATION OF PARTICLE-SIZE DISTRIBUTIONS FROM PROPPANT INTERACTIONS WITH TIGHT RESERVOIR ROCKS

A series of laboratory experiments were performed in which a 2 percent KCl solution was pumped through simulated sand-packed fractures between core halves representing three different tight reservoir formations. During these fluid injections, the core assemblies were subjected to typical overburden pressures ranging from 500 to 9,000 psig, and effluent samples of particle-liquid mixtures were collected  for analysis with a particle-counting apparatus (1).- These analyses typically include the particle concentrations as well as the means, modes, medians, and size ranges of these mixtures. This data, except for the particle concentrations, was obtained in the form of particle-size distribution curves. The degree of plugging of similar types of hydrocarbon-producing formations experienced in the field can be anticipated and then reduced by proper engineering techniques.

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Dynamic Enhanced Recovery Technologies Class I (Final Report Part II)

The AKCESS.Basin Modeling System was developed to investigate phenomena associated with hydrocarbon migration up the Red Fault of the South Eugene Island Minibasin. It is thought that hydrocarbons moved up this fault to charge Pennzoil's Block 330 oil and gas fields, which are among the largest accumulations of oil and gas in the Gulf of Mexico. Because the strata that host the oil and gas reservoirs are less than 1.5 rna old, and some only -0.46 rna, because there are temperature anomalies along the Red Fault that are of the form that pulses of fluid flow up the fault might produce, and because some of the Pennzoil Reservoirs have produced more oil than is conventionally thought possible (up to and perhaps more than 100% of the oil originally in place), it is thought that hydrocarbon migration up the Red Fault may have occurred very recently of be taking place at the present day. As part of this project the Red Fault was drilled to investigate these possibilities. The fault was drilled at the transition zone between soft and hard overpressure; massive amounts of data were collected and analyzed. The part of the project reported here is concerned with modeling. Our charge was to development a modeling methodology capable of realistically addressing temperatures and fluid flow in a data cube centered on the drilled portions of the Red Fault. The modeling was to be of large enough scale to encompass phenomena associated with and recent hydrocarbon migration up the Red Fault The models were to address:  (1) the cause of pressure, temperature, t1uid chemical, and porosity anomalies near the Red Fault,  (2) the possible sources of oil and gas moving up the fault, and (3) the causes of organic and inorganic chemical alteration near the fault.

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DYNAMIC ENHANCED RECOVERY TECHNOLOGIES CLASS I-Part 2

The ACESS Basin Modeling System was developed to investigate phenomena associated with hydrocarbon migration up the Red Fault of the South Eugene Island Minibuses. It is thought that hydrocarbons moved up this fault to charge Pennzoil's Block 330 oil and gas fields, which are among the largest accumulations of oil and gas in the Gulf of Mexico. Because the strata that host the oil and gas reservoirs are less than 1.5 ma old, and some only -0.46 ma, because there are temperature anomalies along the Red Fault that are of the form that pulses of fluid flow up the fault might produce, and because some of the Pennzoil Reservoirs have produced more oil than is conventionally thought possible (up to and perhaps more than 100% of the oil originally in place), it is thought that hydrocarbon migration up the Red Fault may have occurred very recently of be taking place at the present day. As part of this project the Red Fault was drilled to investigate these possibilities. The fault was drilled at the transition zone between soft and hard overpressure; massive amounts of data were collected and analyzed.

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SCALE-UP OF MISCIBLE FLOOD PROCESSES FOR HETEROGENEOUS RESERVOIRS

The current project is a systemic research effort aimed at quantifying relationships between process mechanisms that can lead to improved recovery from gas injection processes performed in heterogeneous Class 1 and Class 2 reservoirs.  It will provide a rational basis for the design of displacement processes that take advantage of crossflow due to capillary, gravity and viscous forces to offset partially the adverse effects of heterogeneity.

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INTEGRATION OF ADVANCED GEOSCIENCE AND ENGINEERING TECHNIQUES TO QUANTIFY INTERWELL HETEROGENEITY IN RESERVOIR MODELS

The goal of this project is to provide a more quantitative definition of reservoir heterogeneity. This objective will be accomplished through the integration of geologic, geophysical, and engineering databases into a multidisciplinary understanding of reservoir architecture and associated fluid-rock and fluid-fluid interactions. The intent is to obtain a quantitative reservoir description incorporating outcrop, field, well-towell, and laboratory core and fluid data of widely varying scales. This interdisciplinary effort will integrate geological and geophysical data with engineering and petrophysical results through reservoir simulation to quantify reservoir architecture and the dynamics of fluid-rock and fluid-fluid interactions. A more accurate reservoir description will allow greater accuracy and confidence during simulation and modeling as steps toward gaining greater recovery efficiency from existing reservoirs.

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Reservoir Characteristics, Production Characteristics, and Research Needs for Fluvial/Alluvial Reservoirs in the United States

The Department of Energy's (DOE's) Oil Recovery Field Demonstration Program was begun in 1992 to maximize the economically and environmentally sound recovery of oil from known domestic reservoirs and to preserve access to this resource. Cost-shared field demonstration projects have been initiated for geologically defined reservoir classes. The reservoir classes have been ranked by their potential for incremental recovery and their risk of abandonment. This document defines the characteristics of the fifth geological reservoir class in the series, fluvial/alluvial reservoirs. The reservoirs of Class 5 include deposits of alluvial fans, braided streams, and meandering streams. Deposit morphologies vary as a complex function of climate and tectonics and have a high degree of fluid-flow heterogeneity due to extreme variations in water energy when the deposits formed.

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Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of c02 Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales

The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO2 enhanced oil recovery project in the Buena Vista Hills field. The Buena Vista Hills pilot CO2 project will demonstrate the economic viability and widespread applicability of CO2 flooding in fractured siliceous shales reservoirs of the San Joaquin Valley. The research consists of four primary work processes: Reservoir Matrix and Fluid Characterization; Fracture Characterization; Reservoir Modeling and Simulation; and, CO2 Pilot Flood and Evaluation. Work done in these areas can be subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced EOR pilot in the West Dome of the Buena Vista Hills field.

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Are Gulf Coast Oil Reservoirs Being "Recharged"?--The Lamont-Doherty Project

The Lammont-Doherty Earth Observatory at Columbia University is leading a team of researchers studying the possibility that offshore Gulf Coast oil reservoirs are being "recharged" by oil flowing upward through fault zones. The possibility of active recharging of oil reservoirs is evident in production histories from tracts in the study area. The DOE cost-shared field demonstration is providing insights into new ways to produce oil reservoirs deep below the salt formations underlying the Gulf of Mexico. Data from the research could reveal how some oil reservoirs are filled in the Gulf and other similar basins. The focus is on "growth faults," structural pathways leading from deep oil sources upward to shallower reservoirs. While conventional petroleum geology measures the rate of upward migration of hydrocarbons from their deep sources in hundreds of thousands of years, the Lamont-Doherty researchers are detecting evidence that oil may be flowing to shallower reservoirs much more rapidly through these growth faults, perhaps in only decades. If this geologic model is accurate, it may mean that certain reservoirs are actually being replenished during their productive life. This could lead to recovery of more oil than one-time "snapshot" estimates would indicate. Equally important is the potential for producers to use growth faults as shortcuts to tap deeper hydrocarbon accumulations. Seismic modeling technology in four dimensions-multiple 3-D seismic surveys conducted over a period of years-has been developed in this project to locate areas in which fluid migration is replenishing reservoirs or oil bearing areas that are not being depleted by the existing wells. The firs well drilled as a result of the 4-D seismic technology initially produced 1500 barrels per day. This well will provide federal royalties worth the full project value within five years (any tax benefits are additional). Because of the huge potential benefit of this technology, an industry consortium is funding post-project refinements of the 4-D technology.

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Log Evaluation of Compacted Shaly Sands of the Mesaverde Group, Uinta Basin, Utah

The Gas Producing Enterprises/DOE MHF demonstrations in the Uinta Basin, Utah, constitute an important part of the FY 78 Western Gas Sands Project, Extensive coring and logging of CIGE 21-15-10-22, a Mesaverde test in the Bitter Creek Field, has provided a multitude of formation evaluation data, This paper analyzes log quality problems in the Mesaverde. Crossplot techniques are used to establish log validity, evaluate formation log parameters, and to provide methods for data normalization. Specific recommendations are made to improve the reliability of Mesaverde log evaluations.

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Environmental and Economic Assessment of Discharges from Gulf of Mexico Region Oil and Gas Operations

To increase scientific knowledge concerning: 1) the fate and environmental effects of organics, trace metals, and NORM in water, sediment  and biota: 2) characteristics of produced water and sand discharges as they pertain to organics, trace metals and NORM viability;  3) recovery of three terminated produced water discharge sites in wetland and open bays; 4) economic and energy supply impacts of existing  and anticipated federal and state offshore and coastal discharge regulations; and 5) catch, consumption and human use patterns of seafood species collected from coastal and offshore waters.

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A Focus on Offshore Safety: Recent Reports by the Marine Board of the National Research Council

During the last three years, the Marine Board of the National Research Council (NRC) has published four study reports that focused on enhancing safety in offshore oil and gas activities and in the marine and maritime fields. The objective of these studies was to provide recommendations for actions that will reduce or eliminate deaths and injuries, reduce pollution from accidents and operations, and protect resources and structures from loss. Several recurring themes are woven through many of these reports. The themes deal with using technology already available and demonstrated, using risk analyses to establish priorities for use of resources (such as inspection facilities and personnel) despite the lack of data for decision making, using advanced tools for inspection and monitoring, and using long-term monitoring to gauge performance. One report about improving marine pipeline safety describes the safety challenges associated with designing, regulating, and monitoring over 20,000 miles of underwater pipelines in federal and state waters. The report on the restoration and protection of marine habitats comments on the institutional, regulatory, and managerial impediments to the wider application of the best engineering technologies and practices and the ways to deal with these impediments. The report on assessment techniques for removing offshore structures provides guidance on the use of technologies and their associated hazards and the development of strategies to mitigate environmental damage when offshore structures must be removed. One of the most recent reports describes a concept for using present undersea vehicles technology and systems to perform tasks that respond to the need to monitor the condition of offshore pipelines and seabed facilities. Two studies now underway continue several of the themes noted in aforementioned reports: one theme being a review of the uses of risk assessment opportunities in an effort to find useful experience from other industries. Another current study targets the introduction of human performance and organizational system theory and practice from other industries into the maritime and offshore industries.

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ON THE DEVELOPMENT OF A WIRELINE TOOL FOR IN SITU STRESS MEASUREMENT BY HYDRAULIC FRACTURING

The present paper is a preliminary progress report of a DOE program at Terra Tek, Inc. to develop a wireline tool for in situ stress measurements by hydraulic fracturing. In addition, a laboratory and analytical study are underway to determine the feasibility of in situ stress measurement through the casing (via perforation). This program could fill the gap that currently exists in the commercial application of in situ stress determination as a design tool for MHF stimulation of tight formations. The paper will be split in two parts. The first part discusses the aspects of the wireline tool, while the second part deals with the measurements of in situ stress through casing perforations.

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NACIMIENTO MOUNTAINS-HISTORY AND RELATION TO THE SAN JUAN BASIN

The present San Juan Basin, a Loromide structural feature, has as its eastern boundary the Nacimiento and Son Pedro Mountains an uplift some 45 miles in length and about 15 miles wide, with a fault of several thousand feet displacement marking the division between uplift and basin. The general Nacimiento-San Pedro Mountain area was uplifted during parts of the Paleozoic; this ancestral positive feature is referred to as the Penasco axis or highland. The present expression of the Nacimiento-San Pedro Mountains had its beginning during the Laramide revolution.

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MULTIWELL EXPERIMENT CORE ANALYSIS OF THE MWX-1, MWX-2, MWX-3

Although a large quantity of core permeability data was provided for the coastal interval, some additional measurements were made(Table I), primarily for the purpose of isolating specific candidates for further testing. Beyond the benefit of adding to the Multiwell data base, this supplemental data allows comparison with the existing data. In general, gas permeabilities measured by DS, while still in the microdarcy range, tend to be lower than the values reported by Core Labs. This of course could simply be a function of sampling and therefore there is no reason to believe that the Core Lab values are not representative. As requested, an attempt at simulating and evaluating the effects of introducing foam into the red and yellow sands of the coastal interval has been made. The primary purpose of this testing was to gain some feeling for the potential for permeability degradation and leak off.

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MODELING OF NON- CONTINUOUS FORT UNION AND MESAVERDE SANDSTONE RESERVOIRS, PICEANCE BASIN, NORTHWESTERN COLORADO

A recent FPC study indicated up to 600 trillion feet of natural gas in place in the Rocky Mountains in low permeability Cretaceous and Tertiary, nonmarine sandstones.  This type of reservoir rock has been studied in the surface and subsurface in the Piceance Basin area of northwestern Colorado. The sandstone geometry and orientation are characterized in this paper. A random intersection" technique is developed that utilizes the geological information to generate a spectrum of reservoir models that may be used to simulate the performance of hydraulically and nuclear fractured wells. An example reservoir model for a nuclear fractured well is compared to a reservoir model for a nonfractured well. In general, the point bar sandstones can be simulated by radial models and the channel sandstones by linear models. In a sequence of channel sandstones with Piceance Basin geometry, an average well will be connected to about 180/0 of the in-place reservoir volume in a 320- acre area. Connected reservoir volumes of greater than 70% in a 320-acre area are calculated for fractured wells, with actual values depending upon fracture extent and pervasiveness. The percent of connected reservoir volume decreases as well spacing increases.

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ADVANCED SECONDARY RECOVERY PROJECT FOR THE SOONER "D" SAND UNIT, WELD COUNTY, COLORADO

The objective of this project was to increase production at the Sooner D Sand Unit through geologically targeted infill drilling and improved reservoir management of waterflood operations. The Sooner D Sand Unit demonstration project should be an example for other operators to follow for reservoir characterization and exploitation methodologies to increase production by waterflood from the Cretaceous D Sandstone in the Denver-Julesburg (D-J) Basin. This project involved multi- disciplinary reservoir characterization using high-density 3D seismic7 detailed stratigraphy and reservoir simulation studies. Infill, water-injection conversion and re-completing some wells to add short-radius laterals were based on the results of the reservoir  characterization studies. Production response were evaluated using reservoir simulation and production tests. Technology transfer utilized workshops, presentations and technical papers which emphasized the economic advantages of implementing the demonstrated technologies.

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Improved Oil Recovery in Fluvial Dominated Deltaic Reservoirs of Kansas - Near-Term

Common oil field problems exist in fluvial dominated deltaic reservoirs in Kansas. The problems are poor waterflood sweep efficiency and lack of reservoir management. The poor waterflood sweep efficiency is due to 1) reservoir heterogeneity, 2) channeling of injected water through high permeability zones or fractures, and 3) clogging of injection wells due to solids in the injection water. In many instances the lack of reservoir management results from 1) poor data collection and organization, 2) little or no integrated analysis of existing data by geological and engineering personnel, 3) the presence of multiple operators within the field, and 4) not identifying optimum recovery techniques.

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MASSIVE HYDRAULIC FRACTURE CONTAINMENT AND PRODUCTIVITY ANALYSES OF MEC MUSE-DUKE WELL #1

Recently a massive hydraulic fracture {MHF) treatment was performed in Mitchell Energy well Muse-Duke #1. The fracture is intended to stimulate gas production from the Cotton Valley Limestone formation. Almost 900~000 gallons of fracturing fluid and 2.8 million pounds of sand proppant were pumped in the fracture. It was estimated that a fracture 210 feet high by 5400 feet long (2700 feet each wing) would be generated. The treatment is intended to drain 640 acres of reservoir. As part of a DOE/Mitchell Energy joint project, Terra Tek has provided laboratory and field measurements in support of the design of this stimulation treatment. Furthermore~ the post stimulation treatment has been predicted based on various measured parameters. This report presents the data obtained in the laboratory and field program and their implications on the economics of MHF stimulation of tight gas formations at the Cotton Valley, Texas fields. Laboratory mechanical properties and field in situ stress measurements were performed to evaluate the containment of a MHF treatment. To assess productivity of the MHF treated well, laboratory tests were performed to determine the interaction between  various fracturing fluids, proppant concentration and the limestone cores. All the laboratory tests were performed under simulated in situ conditions and treatment schedule.

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THE UNIVERSITY OF TULSA PROJECT -Using Horizontal Drilling to Improve Waterflooding

In most older U.S. oil fields water is injected into the reservoir to move the oil to producing wells.  In many formations, however, waterflooding is limited by reservoirs that are segmented into isolated compartments by variations in the reservoir rock. Water injected into these fields is often difficult to control and may fail to sweep efficiently through the formation, leaving behind significant amounts of unproduced oil.

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Screening Criteria for Application of Carbon Dioxide Miscible Displacement in Waterflood Reservoirs Containing Light Oil

In conjunction with a joint Texaco/DOE research project, the LSU Department of Petroleum Engineering developed an improved method of screening reservoirs for application of a carbon dioxide miscible enhanced oil recovery (EOR) process. This method, which can be applied to a large number of reservoirs, considers both the technical and economic feasibility of the EO R process. The technical parameters of each reservoir are first compared to those of an "ideal" reservoir; and from that comparison, each reservoir is assigned a technical ranking. The technical ranking is used to estimate expected recovery. Key technical parameters used in the screening process are remaining oil in place, minimum miscibility pressure, reservoir depth, oil API gravity, and formation dip angle. The reservoirs are subsequently screened for economic feasibility based on standardized capital costs and operation expenses that are representative of the reservoirs under consideration. The reservoirs are formally ranked based on the present worth value of revenues to costs ratio.

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