AndreaBozzo/ceres-open-data-index huggingface dataset:
MULTIFREQUENCY CROSSHOLE EM IMAGING FOR RESERVOIR CHARACTERIZATION

Electrical conductivity of sedimentary rocks is controlled by the porosity, hydraulic permeability, temperature, saturation, and the pore fluid conductivity. 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 induces 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.

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Post Waterflood C02 Miscible Flood in Light Oil Fluvial - Dominated Deltaic Reservoirs

The Post Waterflood C02 Miscible Flood in Light Oil Fluvial Dominated Deltaic Reservoirs is a Class I DOE-sponsored field demonstration project of a C02 miscible flood project at the Port Neches Field in Orange County, Texas. The project will determine the recovery efficiency of CO, flooding a waterflooded and a partial waterdrive sandstone reservoir at a depth of 5800'. The project will also evaluate the use of a horizontal C02 injection well placed at the original oil-water contact of the waterflooded reservoir. A.PC-based reservoir screening model will be developed by Texaco's research lab in Houston and Louisiana State University will assist in the development of a database of fluvial-dominated deltaic reservoirs where CO, flooding may be applicable. This technology will be transferred throughout the oil industry through a series of technical papers and industry open forums.

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ADVANCED UNDERGROUND GAS STORAGE CONCEPTS REFRIGERATED-MINED CAVERN STORAGE

Limited demand and high cost has prevented the construction of hard rock caverns in this country for a number of years. The storage of natural gas in mined caverns may prove technically feasible if the geology of the targeted market area is suitable; and economically feasible if the cost and convenience of service is competitive with alternative available storage methods for peak supply requirements. It is believed that mined cavern storage can provide the advantages of high delivery rates and multiple fill withdrawal cycles in areas where salt cavern storage is not possible. In this research project, PB-KBB merged advanced mining technologies and gas refrigeration techniques to develop conceptual designs and cost estimates to demonstrate the commercialization potential of the storage of refrigerated natural gas in hard rock caverns. Five regions of the U.S.A. were studied for underground storage development and PB-KBB reviewed the literature to determine if the geology of these regions was suitable for sitting hard rock storage caverns. Area gas market conditions in these regions were also studied to determine the need for such storage. Based on an analysis of many factors, a possible site was determined to be in Howard and Montgomery Counties, Maryland. The area has compatible geology and a gas industry infrastructure for the nearby market populous of Baltimore and Washington D.C..

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Design, Capital Cost and Economics for the Low Rank Coal Study Volume 1A

The primary scope of this low rank coal study is similar to that of the original baseline case. The results of the original baseline study provided the basis for this study. Thus, the objectives of this study are to: - develop overall material balance, overall utility requirements, and overall flow distributions for the entire coal liquefaction complex. - generate capital cost estimates for the entire complex following the same approach as used in the baseline design. - carry out economic evaluations utilizing the Lotus 1-2-3 Spreadsheet Economic Model developed in the baseline design. - develop an ASPEN PLUS process simulation model with required modification and additions to the baseline model to account for the low rank coal parameters.

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Horizontal Oil Well Applications And Oil Recovery Assessment Volume I: Success of Horizontal Well Technology

VOLUME I: SUCCESS OF HORIZONTAL WELL TECHNOLOGY Horizontal technology has been applied in over 110 formations in the U.S .A. Volume I of this study addresses the overall success of horizontal technology, especially in less-publicized formations, i .e., other than the Austin Chalk, Bakken, and Niobrara. Operators in the U.S.A. and Canada were surveyed on a formation-by-formation basis by means of a questionnaire. Response data were received describing horizontal well projects in 58 formations in the U.S.A. and 88 in Canada. Operators'responses were analyzed for trends in technical and economic success based on lithology (elastics and carbonates) and resource type (light oil, heavy oil, and gas). The potential impact of horizontal technology on reserves was also estimated. A forecast of horizontal drilling activity over the next decade was developed. VOLUME II: APPLICATIONS OVERVIEW Horizontal technology has been applied in a wide variety of applications and reservoir settings. Much information has been published on drilling, completion, and workover systems, took and techniques for these wells, especially for the most active formations. Little has been presented describing overall production and economic success of the technology in the wider range of formation types. In Volume IX of this study, numerous case studies and analyses are presented of horizontal technology projects in each major application and resource type. Field location, geology, production and economic success, reserves increases, and production problems are described for each project. Chapters are presented assessing horizontal applications in light-oil, heavy oil, and gas reservoirs. To broaden the base of formation types, especially with respect to heavy-oil and gas reservoirs, Canadian operations are highlighted in the study along with those in the U.S. A. Additional objectives of the study include an assessment of the technical and economic limits of horizontal technology.

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Post Waterflood C02 Miscible Flood In Light Oil Fluvial Dominated Deltaic Reservoir

The "Post Waterflood CO2 Miscible Flood in Light oil Fluvial Dominated Deltaic Reservoir" is a Class I DOE-sponsored field demonstration project of a CO2 miscible flood project at the Port Neches Field in Orange County, Texas. The project will determine the recovery efficiency of CO2 flooding a waterflooded and a partial waterdrive sandstone reservoir at a depth of 5800'. The project will also evaluate the use of a horizontal CO2 injection well placed at the original oil-water contact of the waterflooded reservoir. A PC-based reservoir screening model will be developed by Texaco's research lab in Houston and Louisiana state University will assist in the development of a database of fluvial~dominated deltaic reservoirs where CO2 flooding may be applicable. This technology will be transferred throughout the oil industry through a series of technical papers and industry open forums.

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Appendix A

Stress testing (micro-hydraulic fracturing) is recognized by petroleum industry as the most direct method of determining the minimum in situ (closure) stress for a given reservoir rock and the surrounding formations. In general, it is variations of in situ stress between formations that dominates hydraulic fracture height growth and overall fracture geometry. Misleading interpretations of stress test data (cased or open hole) can lead to significant errors in the prediction of stress contrast between the producing and bounding rock layers as well as an erroneous estimation of closure stress in the productive interval. In either case, hydraulic fracture treatment designs based on this information may not be designed optimally and the subsequent interpretation of the fracturing treatment pressure response may not be correct. This paper presents an evolutionary approach in the analysis of stress test data which leads to more consistent results that relate directly to actual fracture treatment pressure responses. Although the emphasis in this paper is on cased hole stress test data interpretation, the methodology presented is also applicable to open hole stress testing and larger scale pump-in/shut-in (i.e. calibration or minifrac) pressure falloff  responses.

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Oil Program Implementation Plan

The goal of the DOE's Oil Program is to better manage our nations oil resources by helping the industry more efficiently and effectively find, develop, and process oil into the desired energy products. The Oil Program Implementation Plan describes the specific technical areas, goals, objectives, and funds required to meet policy goals set by the President, the Secretary of Energy, and Congress. The plan is diverse. It considers the appropriate short- and long-term role of the federal government in petroleum research, the realities facing major oil companies and small independent producers, and the potential impacts of implementing the planned research agenda.

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INVESTIGATION OF OIL RECOVERY IMPROVEMENT BY COUPLING AN INTERFACIAL TENSION AGENT AND A MOBILITY CONTROL AGENT IN LIGHT OIL RESERVOIRS

"Investigation of Oil Recovery Improvement by Coupling an Interfacial Tension Agent and a Mobility Control Agent in Light Oil Reservoirs" is studying two major areas concerning co-injecting an interfacial tension reduction agent and a mobility control agent. The first area defines the interactions of alkaline agents, surfactants, and polymers on a fluid-fluid and a fluid-rock basis. The second area concerns the economic improvement of the combined technology.

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SCALE-UP OF MISCIBLE FLOOD PROCESSES FOR HETEROGENEOUS RESERVOIRS

Progress is reported for a comprehensive investigation of the scaling behavior of gas injection processes in heterogeneous reservoirs. The interplay of phase behavior, viscous fingering, gravity segregation, capillary imbibition and drainage, and reservoir heterogeneity is examined in a series of simulations and experiments. Use of streamtube to model multiphase flow is demonstrated to be a fast and accurate approach for displacements that are dominated by reservoir heterogeneity. The streamtube technique is particularly powerful for multiphase compositional displacements because it represents the effects of phase behavior with a one-dimensional flow and represents the effects of heterogeneity through the locations of streamtubes. A new approach for fast calculations of critical tie-lines directly from criticality conditions is reported. A global triangular structure solution for four-component flow systems, whose tie-lies meet at the edge of a quaternary phase diagram or lie in planes is presented. Also demonstrated is the extension of this solution to multicomponent systems under the same assumptions. The interplay of gravity, capillary and viscous forces on final residual oil saturation is examined experimentally and theoretically. The analysis of vertical equilibrium conditions for three-phase gravity drainage shows that almost all oil can be recovered from the top part of a reservoir. The prediction of spreading and stability of thin film is performed to investigate three phase gravity drainage mechanisms. Finally, experimental results from gravity drainage of crude oil in the presence of C02 suggest that gravity drainage could be an efficient oil recovery process for vertically fractured reservoirs.

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DEVELOPMENT OF COST-EFFECTIVE SURFACTANT FLOODING TECHNOLOGY

This research consists of the parallel development of a new chemical flooding simulator and the application of our existing UTCHEM simulation code to model surfactant flooding. The new code is based upon a completely new numerical method that combines for the first time higher order finite-difference methods, flux limiters, and implicit algorithms. Results indicate that this approach has significant advantages in some problems and will likely enable us to simulate much larger and more realistic chemical floods once it is fully developed. Additional improvements have also been made to the UTCHEM code, and it has been applied to the study of stochastic reservoirs with and without horizontal wells to evaluate methods to reduce the cost and risk of surfactant flooding. During the second year of this contract, we have already made significant progress on both of these tasks and are ahead of schedule on both of them.

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Field Verification of CO2 Foam

The East Vacuum Grayburg/San Andres Unit (EVGSAU), operated by Phillips Petroleum Company, was the site selected for a comprehensive evaluation of the use of foam for improving the effectiveness of a CO2 flood. This project, entitled "Field Verification of CO2-Foam,''was jointly funded by the EVGSAU working interest owners, the U.S. Department of Energy (DOE), and the State of New Mexico. The DOE provided $2 million or approximately 34% of the total project costs, the EVGSAU provided $2.46 million, the State of New Mexico contributed approximately $1.2 million, and about $103,000 of other industrial funds were used. The Petroleum Recovery Research Center (pRRC), a division of the New Mexico Institute of Mining and Technology, provided laboratory and research support for the project. A joint project advisory team composed of technical representatives from several major oil companies provided input, review, and guidance for the project. The project, which began in 1989, had a scheduled duration of four years, but the DOE granted a no-cost extension to the end of March 1995 for the purpose of continued project evaluation. A field test of the CO2-foam has been successfully conducted, and preliminary results are promising. Response in the foam injection well has been as anticipated, and an offset producing well experienced a positive oil response as a result of the foam test. Based on the favorable results observed in the foam injection test, a second foam test was conducted. The monitoring program included analysis of injectivity data, pressure falloff tests, observation well logs, interwell tracer response, production logs, history of production rates, and changes in gas-oil ratio. This report presents an overview of the  project and provides results of the laboratory work, simulation studies, and field tests.

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Advanced Secondary Recovery Demonstration For The Sooner Unit

The objectives of the project are to demonstrate the effectiveness of a multi-disciplinary approach to targeted infill drilling and improved reservoir management. The first phase of the project involves geophysical, geological and engineering data acquisition and analysis to identify optimum well sites and to develop a reservoir operations plan, maximizing secondary recovery using water injection and gas recycling. The second phase will involve drilling of up to three geologically targeted infill wells and establishing production/injection schedules. Reservoir simulation, transient well tests and careful production monitoring will be used to evaluate the results. The third phase will involve technology transfer through a series of technical papers and presentations of a short course. Emphasis will be on the economics of the project and the implemented technologies.

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Revitalizing a Mature Oil Play: Strategies for Finding and Producing Unrecovered Oil in Frio Fluvial-Deltaic Sandstone Reservoirs of South Texas

Fluvial-deltaic sandstone reservoirs represent significant opportunities for re-development in mature fields throughout the world. They presently account for more than 34 billion barrels of unrecovered oil resources in the United States and, as a class, represent the highest percentage of remaining mobile oil resources in clastic reservoirs throughout the state of Texas (Figure 1). The stratigraphic complexity inherent in these deposits is responsible for recovery efficiencies in large part because of the isolation of significant volumes of mobile oil in undeveloped reservoir compartments (Figure 2). These unproduced zones can be identified by integrated geological and engineering reservoir characterization and targeted for incremental recovery by recompletions and infill drilling.

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Sub-Salt Seismic Imaging Program

Advance 3-D seismic technology for imaging sedimentary structures lying beneath salt bodies in the Gulf of Mexico by developing capabilities in 3-D prestack depth migration. The project will research and develop migration computer algorithms, define optimum computer architectures, specify data input/output systems, develop methods of seismic velocity analysis/estimation, and evaluate technologies for visualizing and interpreting seismic images for geological structure and reservoir description.

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Post Waterflood C02 Miscible Flood in Light Oil Fluvial - Dominated Deltaic Reservoirs

Production from the Marg Area 1 at Port Neches is averaging 337 BOPD for this quarter. The production drop is due to fluctuation in both GOR and BS&W on various producing wells, low water injectivity in the reservoir and shut-in one producing well to perform a workover to replace a failed gravel pack setting. Coil tubing work was performed on 2 injection wells in order to resume injection of water and CO, in the reservoir. The Marg Area 2 did not respond favorably to CO, injection in the Kuhn #6 well. For this reason Texaco will not pursue any further development of this section of the reservoir due mainly to low target reserves. Instead Texaco will reallocate the money to a new Marg segment (Marg Area 3) in order to test a new process that will utilize the CO, to accelerate the primary production rates and reduce cycle time. Also the process should reduce water disposal cost, cash lifting cost, operating cost and increase the NPV of the reserves.

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Design and Implementation of a CO2 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells in a Shallow Shelf Carbonate Approaching Waterflood Depletion

The first objective is to utilize reservoir characterization and advanced technologies to optimize the design of a CO2 project for the South Cowden Unit (SCU) located in Ector County, Texas. The SCU is a mature, relatively small, shallow shelf carbonate unit nearing waterflood depletion. The second objective is to demonstrate the performance and economic viability of the project in the field. The work reported here is on the reservoir characterization and project design objective. This objective is scheduled to be completed in early 1996 at which time work on the field demonstration phase is scheduled to begin.

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Increased Oil Production and Reserves from Improved Completion Techniques in the Bluebell Field, Uinta Basin, Utah

The Bluebell field produces from the Tertiary lower Green River and Wasatch Formations of the Uinta Basin, Utah. The productive interval consists of thousands of feet of interbedded fractured clastic and carbonate beds deposited in a fluvial dominated deltaic lacustrine environment. Although some wells have produced over 1 million barrels (1 59,000 m3) of oil, many have produced only 100,000 to 250,000 barrels (1 5,000-31,000 m3), or less, of oil.

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Problem Formulation and Thermal Diffusion and Gravity Segregation

Very large compositional variation both aerially and vertically has been observed in some hydrocarbon reservoirs. Several mechanisms are believed to contribute to such variations. These include: 1) gravitational segregation, 2)molecular diffusion, 3) thermal diffusion, and 4) thermal convection. At isothermal conditions only gravitational segregation and molecular diffusion contribute to vertical compositional grading. The Gibbs segregation concept can properly account for this process. Under nonisothermal conditions, which is often the case, the process is thermodynamically irreversible and therefore Gibbs criteria of equilibrium cannot be invoked.

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THE CLASS ACT

The Class Act is a quarterly newsletter devoted to providing information about DOE?s Reservoir Class Program and presenting results from specific field demonstration projects. The newsletter is produced by BDM-Oklahoma, who manages the National Oil Program for the Department of Energy (DOE) and operates the National Institute for Petroleum and Energy Research (NIPER), a DOE petroleum research laboratory in Bartlesville, Oklahoma. This first issue focuses on Class 1 activities and results, highlighting the technologies used, the profit potential from applying technology, and results of two specific field demonstration projects.

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CHARACTERIZATION OF OIL AND GAS WASTE DISPOSAL PRACTICES AND ASSESSMENT OF TREATMENT COSTS

This study examines wastes associated with the onshore exploration and production of crude oil and natural gas in the United States. The objective of this study was to update and enhance the current state of knowledge with regard to oil and gas waste quantities, the potential environmental impact of these wastes, potential methods of treatment, and the costs associated with meeting various degrees of treatment. To meet this objective, the study consisted of three tasks: 1) the development of a Production Environmental Database (PED) for the purpose of assessing current oil and gas waste volumes by state and for investigating the potential environmental impacts associated with current waste disposal practices on a local scale; 2) the evaluation of available and developing technologies for treating produced water waste streams and the identification of unit process configurations; and 3) the evaluation of the costs associated with various degrees of treatment achievable by different treatment configurations. An updated assessment of the annual domestic production volume of drilling waste and produced water by onshore drilling and production activity showed there to be a general decline in the volumes of drilling waste being produced over the period 1985 - 1992 as well as an apparent reduction in the volume of produced water generated since 1986. A 59% reduction in the volume of drilling waste over 1985 levels was estimated. This reduction is tied to a reduction in the amount of drilling activity and, more closely, to a reduction in the amount of drilled footage taking place. Current estimates show that some 150 million barrels of drilling waste and 18.3 billion barrels of produced water are being generated annually. An analysis of the environmental settings surrounding oil and gas activities in 8 Texas counties showed that local conditions can be far different from those described by the EPA in their nationwide study and used in their risk assessment. The evaluation of feasible technologies for the treatment of produced water waste streams was handled in the context of comparing the level of treatment achievable with the associated cost of treatment. Treatment processes were evaluated for the removal of four categories of produced water contaminants: particulate material, volatile organic compounds, absorbable organic compounds, and dissolved inorganic species. Results showed dissolved inorganic species to be the most costly to remove. The potential cost of treating all 18.3 billion barrels of produced water generated in a year amounts to some 15 billion dollars annually.

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