AndreaBozzo/ceres-open-data-index huggingface dataset:
GEOLOGICAL AND PETROPHYSICAL CHARACTERIZATION OF THE FERRON SANDSTONE FOR 3-D SIMULATION OF A FLUVIAL-DELTAIC RESERVOIR

The objective of the Ferron Sandstone project is to develop a comprehensive, interdisciplinary, quantitative characterization of a fluvial-deltaic reservoir to allow realistic inter-well and reservoir-scale models to be developed for improved oil-field development in similar reservoirs world-wide. Quantitative geological and petrophysical information on the Cretaceous Ferron Sandstone in east-central Utah will be collected. Both new and existing data will be integrated into a three-dimensional model of spatial variations in porosity, storativity, and tensorial rock permeability at a scale appropriate for inter-well to regional-scale reservoir simulation. Simulation results could improve reservoir management through proper infill and extension drilling strategies, reduction of economic risks, increased recovery from existing oil fields, and more reliable reserve calculations. Transfer of the project results to the petroleum industry is an integral component of the project. This report covers research activities for fiscal year 1993-94, the first year of the project. Most work consists of developing field methods and collecting large quantities of existing and new data. We also developed preliminary regional and case-study area interpretations.

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ANISOTROPY AND SPATIAL VARIATION OF RELATIVE PERMEABILITY AND LITHOLOGIC CHARACTER OF TENSLEEP SANDSTONE RESERVOIRS IN THE BIGHORN AND WIND RIVER BASINS, WYOMING

This research will associate spatial distributions and anisotropy of relative permeability with the depositional surfaces and zones of diagenetic alteration found within the Tensleep Sandstone. The associations between depositional lithofacies diagenetic alteration, and pore geometry will link relative permeability with the distinct and measurable dimensions of lithofacies, and authigenic mineral facies. Effects of the depositional processes and burial diagenesis will be investigated.

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AN EXPERIMENTAL AND THEORETICAL STUDY TO RELATE UNCOMMON ROCK/FLUID PROPERTIES TO OIL RECOVERY

The most commonly used secondary oil recovery technique is waterflooding. Macroscopic (or ammon) rock-pore characteristics such as pomity, permeability and irreducible water saturation and fluid properties such as viscosity have ken shown by pious investigators to influence the results of waterflooding and consequently ultimate oil recovery. The objectives of this study are to consider the influence of microscopic (or uncommon) rock-pore characteristics such as wetability, tortuosity, mercury intrusion volume, pore surface am, specific surface area, average pore diameter, median pomthmat diameter, pore length, apparent (skeletal) density and mercury recovery efficiency on residual oil saturation and oil recovery mlilzed in linear-core waterfloods. The mults were statistically analyzed to determine the quantitative relations between the various properties, and empirical equations were developed for predicting waterflood performance. The characteristics were analyzed and modeled at both breakthrough and floodout.

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Post Waterflood CO, Miscible Flood in Light Oil, Fluvial-Dominated Deltaic Reservoir

Production from the Marg 1 area at Port Neches is averaging 392 BOPD for this quarter.  The production drop is due to fluctuations in both GOR and BS&W on the various producing wells, coupled with low water injectivity in the reservoir.  We were unable to inject any tangible amount of water in the reservoir since late January.

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ADVANCES IN STEADY-AND UNSTEADY-STATE RELATIVE PERMEABILITY MEASUREMENTS AND CORRELATIONS FY1995

This report describes the results of tests performed to support development of low cost, simple methods for estimating fluid transmission characteristics of reservoir rocks; to improve accuracies of laboratory measured rock fluid transmission characteristics for reservoir engineering designs and recovery predictions; and to provide data and descriptions from multiphase fluid tests to support coreflood and reservoir simulator developments.

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ELECTRICAL AND ELECTROMAGNETIC METHODS FOR RESERVOIR DESCRIPTION AND PROCESS MONITORING

One of important geophysical parameters that can be used to help monitor and characterize a petroleum reservoir is the electrical conductivity. The electrical conductivity of rock is dominantly a function of fluid type, its saturation, the porosity, and hydraulic permeability of the rock. For these reasons, resistivity well logs have long been used by geologists and reservoir engineers in petroleum industries to map variations in pore fluid, to distinguish between rock types, and to determine completion intervals in wells. It is therefore a natural extension to use the electrical conductivity structure to provide additional information about the reservoir. Reservoir simulation and process monitoring rely .heavily on the physical characteristics of the reservoir model. At present, numerical codes use point measurements of porosity, permeability, and fluid saturation and extrapolate these data throughout a three-dimensional  (3-D) grid. The knowledge of a high-resolution geophysical parameter such as electrical conductivity would aid this extrapolation and improve the reservoir simulation effort. In addition, sine conductivity is sensitive to changes in the composition and state of fluids in pores and fractures it becomes an ideal method for monitoring a reservoir process

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ELECTRICAL AND ELECTROMAGNETIC METHODS FOR RESERVOIR DESCRIPTION AND PROCESS MONITORING

It is well known that electrical conductivity of rock is closely related to the porosity, hydrologic permeability, saturation, and the type of fluid in it. These rock parameters play important roles in the development and production of hydrocarbon (petroleum and natural gas) resources. For these reasons, resistivity well logs have long been used by geologists and reservoir engineers in petroleum industries to map variations in pore fluid, to distinguish between rock types, and to determine completion intervals in wells. It is therefore a natural extension to use the electrical conductivity structure to provide additional information about the reservoir. Reservoir simulation and process monitor rely heavily on the physical characteristics of the reservoir model At present, numerical codes use point measurements of porosity, permeability, and fluid satiation and extrapolate these data throughout a three-dimensional (3-D) grid. The knowledge of a high-resolution geophysical parameter such as electrical conductivity would aid this extrapolation and improve the reservoir simulation effort. In addition, since conductivity is sensitive to changes in the composition and state of fluids in pores and fractures it becomes an ideal method for monitoring a reservoir process.

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IMPROVING RESERVOIR CONFORMANCE USING GELLED POLYMER SYSTEMS

The objectives of the research program are to (1) identify and develop polymer systems which have potential to improve reservoir conformance of fluid displacement processes, (2) determine the performance of these systems in bulk and in porous media, and (3) develop methods to predict their performance in field applications. The research focuses on three types of aqueous gel systems - a polysaccharide (KUSPl) that gels as a function of pH, a polyacrylamide-chromium(III) system and a polyacrylamide-aluminum citrate system. This report describes work conducted during the second year of a three-year program. Progress was made in the utilization of KUSP 1 as a gelling agent. It was shown that gels can be formed in situ in porous media using CO2 or ester hydrolysis to lower pH. An ester was identified that could be used in field-scale operations. It was determined that KUSPI will form strong gels when ortho boric acid is added to the system. It was also determined, in cooperation with Abbott Laboratories, that KUSPI can be produced on a commercial scale. Rheological studies showed that shear rate significantly affects gelation time and gel strength. The effect of rock-fluid interactions at alkaline conditions was examined experimentally and through mathematical modeling. A model was developed that treats non-equilibrium conditions and this is an improvement over previously published models.

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Case Studies on Direct Coal Liquefaction for the Low Rank Coal Study

This study determined the potential economic advantages in operating the coal liquefaction portion of the manufacturing complex at a lower pressure than the pressure used for the low rank coal study. The lower cost of the equipment in the coal liquefaction area has a very significant effect on the economics primarily due to the difference in thickness of the reactors and related equipment. However, the lack of thermodynamic, kinetic, and hydrodynamic data did not allow for a more complete and detailed study of the effect of pressure on the liquefaction process and the subsequent impact on the overall processing complex.

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TORIS: An Integrated Decision Support System for Petroleum E&P Policy Evaluation

TORIS IS AN INTEGRATED SUITE of databases and analytical computer models focused on the U.S. oil resource. It is designed to facilitate the decision-making process integral to the formulation of governmental policy affecting the upstream petroleum sector. The benefits TORIS brings to this process stem from the ability of the system to provide metrics for a wide range of policy scenarios. Specific applications of the system include: ? Evaluation of alternative tax structures at state and federal levels ? Formulation of optimum royalty structures and related transfer payments ? Evaluation of financial concession terms ? Guidance and prioritization of R&D programs ? Evaluation of technology feasibility ? Cost and benefit analysis of environmental and other regulatory legislation

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POROSITY DETERMINED FROM NEUTRON , DENSITY AND SONIC LOGS IN WESTERN TIGHT GAS SANDS

The tight gas sands of the Rocky Mountain Region contain large volumes of gas; yet, to date there is very little production from this region. One of the reasons for the lack of exploration of this valuable reserve may be the inability to accurately evaluate the reserve. The most practical way to evaluate this resource is with wire-line logs. Therefore, research is being conducted in order to determine the best methods of evaluating this reserve.  Specifically, the research is being directed toward evaluating the ability of the neutron, the density and the sonic log to predict the porosity of the subsurface formations.

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A REVIEW OF THE TORIS ADVANCED SECONDARY RECOVERY METHODOLOGY

A prototype methodology for evaluating oil production due to advanced secondary recovery (ASR) processes was fully developed and used by ICF Resources Incorporated in the Multistate analysis which was performed for the Interstate Oil and Gas Compact Commission (IOGCC). As part of Work Request Number AC/l5104/BC/42,Rev. the Department of Energy (DOE) as requested that BDM-Oklahoma review this methodology to determine its suitability for use in TORIS and to suggest changes in the methodology if warranted. This document provides documentation of the methodology currently applied. Its purpose is to provide potential reviewers with the level of understanding necessary to critically review the current approach. Hopefully, by understanding the methodology used in the past, reviewers will be able to brainstorm and develop new ideas both for testing the current methodology as well as developing alternative approaches for resolving any problems.

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ELECTRICAL AND ELECTROMAGNETIC METHODS FOR RESERVOIR DESCRIPTION AND PROCESS MONITORING

One of important geophysical parameters that can be used to help monitor and characterize a petroleum reservoir is the electrical conductivity. The electrical conductivity of rock is dominantly a function of fluid type, its saturation, the porosity, and hydraulic permeability of the rock. For these reasons, resistivity well logs have long been used by geologists and reservoir engineers in petroleum industries to map variations in pore fluid, to distinguish between rock types, and to determine completion intervals in wells. It is therefore a natural extension to use the electrical conductivity structure to provide additional information about the reservoir. Reservoir simulation and process monitoring rely heavily on the physical characteristics of the reservoir model. At present, numerical codes use point measurements of porosity, permeability, and fluid saturation and extrapolate these data throughout a three-dimensional (3-D) grid. The knowledge of a high-resolution geophysical parameter such as electrical conductivity would aid this extrapolation and improve the reservoir simulation effort. In addition, sine conductivity is sensitive to changes in the composition and state of fluids in pores and fractures it becomes an ideal method for monitoring a reservoir process. During FY -91 a coordinated electrical and electromagnetic (em) geophysical research program for petroleum reservoir characterization and process monitoring was initiated. Parties involved in this program include Lawrence Berkeley Laboratory (LBL), Lawrence Livermore Laboratory (LLNL), Sandia National Laboratory (SNL), and University of California at Berkeley (UCB). The overall objectives of the program are:  ? To integrate research funded by DOE for hydrocarbon recovery into a focused effort to demonstrate the technology in the shortest time with the least cost. ? To assure industry acceptance of the technology developed by having industry involvement in the planning, implementation, and funding of the research. ? To focus the research on real world problems that have the potential for solution in the near term with significant energy payoff. Specific research activities conducted through this integrated effort have been in the following five general areas: ? 1) em modeling development ? 2) Data interpretation methods development ? 3) Hardware and instrumentation development. ? 4) EOR and reservoir characterization. ? 5) Controlled field experiments. At LBUUCB research has been focused on activities 1), 2), and 5) in FY92. The primary focus of these activities is in the development of reliable inversion and imaging schemes that can yield conductivity distributions from measured electrical and em field data. The development of accurate forward modeling algorithms and the high-quality scale model experiment are necessarily the early part of the field experiment design and the inversion scheme development for ultimately monitoring the front tracking in existing reservoirs.

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EVALUATION OF A SITE IN HEPLER (KS) OIL FIELD FOR A SURFACTANT-ENHANCED ALKALINE CHEMICAL FLOODING PROJECT AND SUPPORTING RESEARCH

NIPER is conducting a DOE-industry sponsored project to determine the feasibility of applying surfactant-enhanced alkaline flooding technology.  This report focuses on research conducted between October 1993 and September 1994. During this time period, a second field tracer survey was conducted, prior field and laboratory data were reevaluated, additional laboratory research was conducted with field cores (e.g., experiments were conducted to determine if parameters such as transient IFT behavior, core wettability, and unspecified oil properties would affect oil recovery from Hepler field cores), and the project participants decided not to implement field injection of a chemical system designed for a field test on the Elmer C lease of Hepler oil field located in Southeast Kansas. For detailed information on other aspects of the feasibility study and on specific laboratory procedures, the reader is directed to the several reports and publications that resulted from the study.

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Spent Fuel Storage Requirements 1993-2040 Part 1 of 3

Historical inventories of spent fuel are combined with US DOE projections of future discharges from commercial nuclear reactors in the US to provide estimates of spent fuel storage requirements through the year 2040. The needs are estimated for storage capacity beyond that presently available in the reactor storage pools. These estimated incorporate the maximum capacities within current and planned in-pool storage facilities and any planned transshipments of spent fuel to other reactors or facilities. Existing and future dry storage facilities are also discussed. The nuclear utilities provide historical data through December 1992 on the 1993 Form RW-859 "Nuclear Fuel Data" survey. Projected discharges through the end of reactor life are based on the DOE/Energy Information Administration estimated of future nuclear capacity, generation, and spent fuel discharges.

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PRODUCTIVITY AND INJECTIVITY OF HORIZONTAL WELLS

Stanford Project on Productivity and Injectivity of Horizontal Wells has been set up for the purpose of developing advanced performance prediction methods for horizontal wells in heterogeneous reservoirs. The stimulus for this project arises from the fact that HWs are now being drilled in large numbers (e.g., over 4200 HWs drilled in the U.S. to the end of 1993) and their benefits have provided the one example of an advanced oil recovery technique which is proving to be a general economic attraction.

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ELECTRICAL AND ELECTROMAGNETIC METHODS FOR RESERVOIR DESCRIPTION AND PROCESS MONITORING

It is well known that electrical conductivity of rock is closely related to the porosity, hydrologic permeability, saturation, and the type of fluid in it. These rock parameters play important roles in the development and production of hydrocarbon (petroleum and natural gas) resources. For these reasons, resistivity well logs have long been used by geologists and reservoir engineers in petroleum industries to map variations in pore fluid, to distinguish between rock types, and to determine completion intervals in wells. It is therefore a natural extension to use the electrical conductivity structure to provide additional information about the reservoir. Reservoir simulation and process monitoring rely heavily on the physical characteristics of the reservoir model At present, numerical codes use point measurements of porosity, permeability, and fluid saturation and extrapolate these data throughout a three-dimensional (3-D) grid. The knowledge of a high-resolution geophysical parameter such as electrical conductivity would aid this extrapolation and improve the reservoir simulation effort. In addition, since conductivity is sensitive to changes in the composition and state of fluids in pores and fractures it becomes an ideal method for monitoring a reservoir process. At the beginning of FY -91 a coordinated electrical and electromagnetic (EM) geophysical research program for petroleum reservoir characterization and process monitoring was initiated. Parties involved in this program include Lawrence Berkeley Laboratory (LBL), Lawrence Livermore Laboratory (LLNL), Sandia National Laboratory (SNL), and University of California at Berkeley (UCB). The overall objectives of the program were: ? To integrate research funded by DOE for hydrocarbon recovery into a focused effort to demonstrate the technology in the shortest time with the least cost. ? To assure industry acceptance of the technology developed by having industry involvement in the planning, implementation, and funding of the research. ? To focus the research on real world problems that have the potential for solution in the near term with significant energy payoff. Specific research activities conducted through this integrated effort have been in the following five general areas: ? 1) EM modeling development. ? 2) Data interpretation methods development. ? 3) Hardware and instrumentation development. ? 4) EOR and reservoir characterization. ? 5) Controlled field experiments. The primary focus of these activities was in the development of reliable inversion and imaging schemes that could yield conductivity distributions from measured electrical and EM field data. The development of accurate forward modeling algorithms and the high quality scale model experiment are necessarily the early part of the field experiment design and the inversion scheme development for ultimately monitoring the front tracking in existing reservoirs.

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NATURALLY FRACTURED TIGHT GAS RESERVOIR DETECTION OPTIMIZATION

A bug in the temperature equation, which was causing the code to fail during simulation was found and corrected. A new solver, using the partial pivoting method, was developed that reduces numerical rounding error.  Also, coordinates were changed from elliptical to rectilinear in order to agree with the coordinate systems of other program modules being developed. A fracturing module is being implemented that allows subcritical fracture nucleation and growth initiation when fluid pressure exceeds the magnitude of the least principal stress. System penneability and porosity correspondingly increase upon fracturing. Testing and calibration of the fracture module should be completed next month. Work continues on the stress solver. A smoothing technique has been ,implemented in order to reduce numerical noise. Excessively fine grid spacing is required for accurate simulation and improvement of the algoritlun to allow this is being investigated. The code is being reworked step by step to determine if errors in code construction are also contributing to numerical inaccuracy.  The elastic module of the finite element stress solver is complete. The viscoelastic module is coded and is being tested for various boundary conditions and the addition of pore pressure. Preliminary comparison of the predictions of the finite element code with analytical solutions for simple and/or published results suggests that the second order finite element method being used is ideal for simulating basin stresses and deformation. The next step will involve stress analysis of the Piceance Basin and refinement of the code to reduce computing time. The combined chemistry and pressure solver is being tested for simulations of a hypothetical basin. The sediment input module for the three-dimensional simulator has been further refined to facilitate data input.

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NATURALLY FRACTURED TIGHT GAS RESERVOIR

The project entitled Naturally Fractured Tight Gas Reservoir Detection Optimization is a multi-year project designed to predict the intensity and geometry of natural fracture systems in the subsurface. The presence of naturally fractured reservoirs is a requirement for commercial production from the vast storehouse of natural gas held in tight gas reservoirs.  In the past, numerous techniques have been used to identify fractured zones. One of the most promising techniques involves the use of shear wave birefringence to delineate fractured reservoir geometries. Unfortunately, the expense of the technique precludes its use as an exploration tool over large areas. These surface seismic fracture detection technologies, however, may be cost-effective if they are applied to regions where fractures are already known to exist. Current methods to locate fractures in a large tight gas basin are too imprecise to justify the commitment of using advanced seismic methods to verify their location and characteristics.

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FINAL REPORT ON EVALUATION OF CYCLOCRAFT SUPPORT OF OIL AND GAS OPERATIONS IN WETLAND AREAS

The cyclocrane hybrid aircraft was developed by Aerolift, Inc. at Tillamook, Oregon from 1978 through 1990. Aerolift demonstrated the technical viability of the single-rotor version of the aircraft by the accomplishment of several developmental programs, including the successful manned free-flight operations of the two-ton payload demonstration Cyclocrane X.2, shown in Figure 1.

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