AndreaBozzo/ceres-open-data-index huggingface dataset:
WETTABILITY AND PREDICTION OF OIL RECOVERY FROM RESERVOIRS DEVELOPED WITH MODERN DRILLING AND COMPLETION FLUIDS

The objectives of this project are: 1) to improve understanding of the wettability alteration of mixed-wet rocks that results from contact with the components of synthetic oil-based drilling and completion fluids formulated to meet the needs of arctic drilling; 2) to investigate cleaning methods to reverse the wettability alteration of mixed-wet cores caused by contact with these SBM components; and 3) to develop new approaches to restoration of wetting that will permit the use of cores drilled with SBM formulations for valid studies of reservoir properties.

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APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR

The OXY-operated Class 2 Project at West Welch is designed to demonstrate how the use of advanced technology can improve the economics of miscible CO2 injection projects in lower quality Shallow Shelf Carbonate reservoirs. The research and design phase (Budget Period 1) primarily involved advanced reservoir characterization. The current demonstration phase (Budget Period 2) is the implementation of the reservoir management plan for an optimum miscible CO2 flood design based on the reservoir characterization. Although Budget Period 1 for the Project officially ended 12/31/96, reservoir characterization and simulation work continued during the Budget Period 2. During the fifth and sixth annual reporting periods (8/3/98-8/2/00) covered by this report, work continued on interpretation of the cross well seismic data to create porosity and permeability profiles which were distributed into the reservoir geostatistically. The initial interwell seismic CO2 monitor survey was conducted, the acquired data processed and interpretation started. Only limited well work and facility construction was conducted in the project area. The CO2 injection initiated in October 1997 was continued, although the operator had to modify the operating plan in response to low injection rates, well performance and changes in CO2 supply. CO2 injection was focused in a smaller area to increase the reservoir processing rate. By the end of the reporting period three producers had shown sustained oil rate increases and ten wells had experienced gas (CO2) breakthrough.

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Greater Green River Basin Production Improvement Project

It has been estimated that the Greater Green River Basin of southwestern Wyoming may contain as much as 5,000 TCF of gas trapped within unconventional, over pressured, very tight, basin-cantered gas reservoirs. Among the many potential productive horizons in the Greater Green River Basin (GGRB) is the mid-Cretaceous Frontier Formation, estimated to contain at least 300 TCF of natural gas. The Frontier Formation has been recognized as a very large gas resource for over three decades, and all of the wells penetrating the deep, basin-centered Frontier Formation in the GGRB have encountered gas. However, none of these deep wells that drilled through the over pressured Frontier prior to this project have proven to be economic. This has been due to the very low average permeability within the reservoir (as low as 0.0001 md in situ permeability. The Greater Green River Basin Production Improvement Project (GGRBPIP) has been a multi-year partnership between the oil and gas industry and the U.S. Department of Energy Federal Technology Center (FETC), now the National Energy Technology Laboratory (NETL). The primary objective of the project was to identify and evaluate new technologies to make drilling for and producing this strategic gas resource economically viable. During the last six years, FETC/NETL has worked with Union Pacific Resources (now Anadarko Petroleum Corporation) and their partners Andex Resources, Belco Energy, Yates Texaco, and Flying J, along with the Gas Research Institute, Sandia National Labs, Advanced Resources International, Schlumberger and Baker Hughes to 1) identify optimum drilling locations, 2) reduce drilling time and expense, 3) test new horizontal drilling techniques, 4) evaluate and characterize the reservoir, and 5) establish economically viable production. All of these goals were successfully accomplished.

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Task 6.3/6.7.4 - Silicon Carbide Joining

Future energy systems will be required to fire low-grade fuels and meet higher energy conversion efficiencies than today's systems. The steam cycle used at present is limited to a maximum temperature of 550 "C, because above that the stainless steel tubes deform and corrode excessively. To boost efficiency significantly, much higher working fluid temperatures are required. Although high-temperature alloys will suffice for the construction of these components in the near-term, the greatest efficiency increases can only be reached with the use of advanced structural ceramics such as silicon carbide (SiC). However, SiC does not melt, but instead sublimes at temperatures over 2000 "C. Therefore, it is not possible to join pieces of it through welding, and most brazing compounds have much lower melting points so the joints lose strength at temperatures much lower than the maximum use temperature of the SiC. Since larger objects, such as heat exchangers, cannot be easily created from smaller ceramic pieces, the size of the SiC structures that can presently be manufactured are limited by the size of the sintering furnaces (approximately 10 feet for sintered alpha silicon carbide). In addition, repair of the objects will require the use of field joining techniques. Some success has been made by causing silicon and carbon to react at 1400 0-1 500 "C to form SiC in a joint (Rabin, 1995) but these joints contain continuous channels of unreacted silicon which cause the joints to corrode and creep excessively at temperatures below 1260 "C (Breder, 1996). At present, no joining techniques are available that allow sintered alpha SiC to be used to its full potential.

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ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM

The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

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ALKALINE-SURFACTANT-POLYMER FLOODING AND RESERVOIR CHARECTERAZATION OF THE BRIDGEPORT AND CYPRESS RESERVOIRS OF THE LAWRENCE FIELD

Additional oil and produced water samples were collected for use in completing the laboratory work. Reservoir Characterization The Griggs 107 well has been designated the type well for the pilot study because it has the best core recovery of the six wells cored for the pilot flood. The Cypress Sandstone has been subdivided into five separate reservoir compartments in the pilot area. Graph of permeability measurements in core analysis report shows low permeability rocks separate the A, B, C, D, and E sandstones in the middle Cypress sandstone from one another. Examination of cores show that low permeability units are composed of siltstone, shale and interbedded shale and fine-grained sandstone. These permeability barriers separate reservoir compartments from one another in the Cypress Sandstone. Geophysical logs have been evaluated in each well in the pilot area. Formation depths have been established for all wells and the Cypress sandstone has been subdivided in each well in the pilot area. The Pennsylvanian Bridgeport A, B and D sandstones have also been subdivided in each well in the pilot area.

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Advanced Cuttings Transport Study

Construction and development of the flow loop is continuing. During this quarter, installation of the air/foam system was completed. Generation of foams with a controllable gas/liquid ratio (quality) was achieved according to the design plan. However some problems were initially encountered with controlling back pressure on the flow loop. It was learned that additional programming of the LabView software was necessary in order to vary the gain on the vent valve at the top of the breaker or separation tower. In addition, some difficulties were encountered in breaking the foam at the separation tower. The primary cause of the problem was traced to a faulty pump that injects breaker chemical into the flowing foam. After correcting this pump problem, foam is now being broken and separated into air and water without any problem. Task 9 tests were started during this quarter and will continue into the fall. Efforts continued on the design of a Cuttings Injection/Collection System (Task 3). This is the primary construction task during Year-3. It is anticipated that the design will be submitted to qualified contractors sometime during the fall, 2001.

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AN ADVANCED FRACTURE CHARECTERIZATION AND WELL PATH NAVIGATION SYSTEM FOR EFFECTIVE RE-DEVELOPMENT AND ENHANCEMENT OF ULTIMATE RECOVERY FROM THE COMPLEX MONTEREY RESERVOIR OF SOUTH ELLWOOD FIELD, OFFSHORE CALIFORNIA

Venoco Inc, intends to re-develop the Monterey Formation, a Class III basin reservoir, at South Ellwood Field, Offshore Santa Barbara, California. Well productivity in this field varies significantly. Cumulative Monterey production for individual wells has ranged from 260 STB to 8,700,000 STB. Productivity is primarily affected by how well the well path connects with the local fracture system and the degree of aquifer support. Cumulative oil recovery to date is a small percentage of the original oil in place. To embark upon successful re-development and to optimize reservoir management, Venoco intends to investigate, map and characterize field fracture patterns and the reservoir conduit system. State of the art borehole imaging technologies including FMI, dipole sonic and cross-well seismic, interference tests and production logs will be employed to characterize fractures and micro faults. These data along with the existing database will be used for construction of a novel geologic model of the fracture network. Development of an innovative fracture network reservoir simulator is proposed to monitor and manage the aquifer's role in pressure maintenance and water production. The new fracture simulation model will be used for both planning optimal paths for new wells and improving ultimate recovery.

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Wettability and Imbibition: Microscopic Distribution of Wetting & Its Consequence at the Core and Field Scales

The New Mexico Institute of Mining and Technology, the University of Wyoming and Texas Tech University combined to assemble a multidisciplinary team of engineers (petroleum, mineral and chemical), geologists and chemists with the objective of studying how pore surface wetting is established and how it affects imbibition and fluid flow.

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INCREASED OIL PRODUCTION AND RESERVES UTILIZING SECONDARY/TERTIARY RECOVERY TECHNIQUES ON SMALL RESERVOIRS IN THE PARADOX BASIN, UTAH

The primary objective of this project is to enhance domestic petroleum production by demonstration and technology transfer of an advanced oil recovery technology in the Paradox Basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to about 100 additional small fields in the Paradox Basin alone, and result in increased recovery of 150 to 200 million bbl of oil. This project is designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon dioxide- (CO2-) flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place in the Paradox Basin within the Navajo Nation. The results of this project will be transferred to industry and other researchers through a petroleum extension service, creation of digital databases for distribution, technical workshops and seminars, field trips, technical presentations at national and regional professional meetings, and publication in newsletters and various technical or trade journals.

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Task 6.7.3 - Interfacial Mass Transport Effects in Composite Materials

Advanced metal-matrix composites (MMCS) consisting of titanium-based alloys possess some unique mechanical, physical, and chemical characteristics that make them highly desirable for aircraft and gas turbine engines. Tailoring MMC properties is essential for advanced product design in materials processing. The main factors that affect materials processing and, further, the nature of a metal-ceramic interface, its structure, and morphological stability is liquid surface mass transport related to adhesional wetting (physical effect) and reactive wetting (chemical effect).'   Surfaces and interfaces dominate many of the technologically important processes in composite materials such as liquid-solid sintering and joining. The objective of this work is threefold: 1) to get insight into the role of the nonstoichiometry of chemical composition in ceramic materials used as reinforcement components in MMC processing, 2) to extend previous energetic analysis of mass transport phenomena to wetting behavior between liquid metal and the quasi-solidlike skin resulting from the presolidification of liquid on nonstoichiometric solids on a  scale of interatomic distance, and 3) to provide experimental verification of our concept.

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Southern-Central Appalachian Framework & Control of Hydrocarbon Generation

This project began with the simple concept that there could still be commercial quantities of hydrocarbons in the deeper, Lower Paleozoic sediments below the Appalachian or Eastern Overthrust sheets. Clues had come from trace signs of hydrocarbons detected in water samples from deep wells in the overthrust area.  The program focused on the lithologies and structural/tectonic/thermal/pressure history of the study area. The Oak Ridge-University of Tennessee team gathered detailed information on regional stratigraphy. This allowed the thrust sheets to be palinspastically restored to their original position. Rock and included fluid samples were taken for laboratory analysis. The results showed that there was an area surrounding eastern Tennessee with possible source beds where the rocks and their included fluids have remained within the oil and gas window of thermal maturity. Migration pathways were then identified and studied to locate where the oil and gas can now be found. It was found that most of the hydrocarbons were presently trapped in fracture porosity.

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Realistic Velocity Anisotropy Estimation in Complex 3D Environments Lawrence

Objectives of the Project: -Develop forward modeling, velocity analysis, and migration methods in anisotropic media -Methodology and algorithms developed by this project will improve the quality and resolution of seismic images that are critical to the economic exploration for hydrocarbons -Project to provide critical understanding of the fundamental physics of wave propagation in anisotropic media, which is necessary for the design of optimal seismic surveys used in hydrocarbons exploration

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Challenges to Reliably Measuring the Fundamental Properties of Hydrocarbon Hydrates: A Status Report

Modeling in situ effects of gas hydrates on sediment properties using estimated hydrate properties has many practical applications. Until recently, reliable measurements of such properties were hampered by technical problems, such as the difficulty of making pure materials. These difficulties have been largely overcome using methods developed over the last 5 years, including a simple method for making >99% pure sI and sII hydrates. Preservation of such material by cooling to 77 K has made possible accurate measurements of thermal diffusivity and the ductile rheology of compacted sI methane hydrate possible. By integrating hydraulic compaction and sensors into the synthesis vessel, reliable measurements of wavespeeds (Vp and Vs) and thermal conductivity (k) have been made on compacted sI and sII hydrates. Standout results include discovering hydrocarbon hydrate properties are generally very different from those of ice. For example, sI methane hydrate is 20 to 50 times stronger than ice and has a thermal conductivity less than 20% that of ice.

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Laboratory Thermal Conductivity Measurements in Pure Methane Hydrate Between ?5 and ?30 ?C

The extensive methane (CH4) hydrate deposits found in shallow permafrost and continental margin sediment has generated interest as a potential natural resource, a submarine geohazard, and a contributor to global climate change. The significance of gas hydrate in these roles depends in part on the effects of temperature on their stability, and hence can be sensitive to exchanges of heat with their environment. Thermal properties such as conductivity and diffusivity are therefore important properties governing the response of hydrate-bearing sediment to natural or man-made thermal perturbations. We seek to improve characterizations of hydrate's in situ thermal behavior by making laboratory measurements of thermal conductivity in pure sI CH4 hydrate at near in situ pressures and temperatures.

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51227 Stanford Rock Physics & Borehole Geophysics Consortium

The Stanford Rock Physics and Borehole Geophysics Project (SRB) is a consortium of university and industry researchers who are focusing on the relationship between geophysical data and reservoir fluid and rock properties. The goal is to better interpret seismic data and well logs to better characterize the reservoir and improve well design, completion and production. The SRB research projects involve coordination and cooperation with around 25 industry consortium members. Project selection involves industry interests and participation. The projects have involved: improved exploration/fewer dry holes, better targeting of directional wells, improved design of completion in richest targets, identification of resource behind pipe, identification of bypassed targets, improved design for enhanced recovery operations, recompletion of older wells to recover remaining economical reserves, delayed abandonment of mature fields and improved techniques for environmental programs.

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Seismic Studies of the Blake Ridge: Implications for Hydrate Distribution, Methane Expulsion, and Free Gas Dynamics

I summarize results of active-source seismic investigations, including single-channel seismic reflection, ocean bottom seismic refraction and vertical seismic profiles from the Blake Ridge, offshore South Carolina. The Blake Ridge is a highly dynamic system, in which methane gas is being generated today at depths exceeding 700m and migrates on the sub-MA time scale.

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On-line Optimization-Based Simulators for Fractured and Non-fractured Reservoirs

This report focuses on the results of our own studies aimed at assessing the role of faults and fractures in controlling fluid flow through Navajo Sandstone exposed in Southern Utah (e.g., Shipton et al., 2002; Dunn, 2004). We, and others, have completed similar outcrop-based studies in faults found in sandstone and other rock types (e.g., Aydin, 1978; Forster and Evans, 1991; Antonellini and Aydin, 1994, 1995; Caine et al., 1996; Matthai et al., 1998; Forster et al., 1998; Caine and Forster, 1999; Davis, 1999; Taylor et al., 1999; Maerten et al., 2001; Jourde et al., 2002). The Big Hole Fault (Shipton et al., 2002) and Teasdale Fault Zone (Dunn, 2004) have received much of our attention over the past 5 years because they are well exposed at the surface and provide a wide spectrum of fault type within the relatively uniform sandstone host rock.

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Anomalous Preservation of Pure Methane Hydrate at 1 atm

Direct measurement of decomposition rates of pure, polycrystalline methane hydrate reveals a thermal regime where methane hydrate metastably ?preserves? in bulk by as much as 75 K above its nominal equilibrium temperature (193 K at 1 atm). Rapid release of the sample pore pressure at isothermal conditions between 242 and 271 K preserves up to 93% of the hydrate for at least 24 h, reflecting the greatly suppressed rates of dissociation that characterize this regime. Subsequent warming through the H2O ice point then induces rapid and complete dissociation, allowing controlled recovery of the total expected gas yield. This behavior is in marked contrast to that exhibited by methane hydrate at both colder (193-240 K) and warmer (272- 290 K) test conditions, where dissociation rates increase monotonically with increasing temperature. Anomalous preservation has potential application for successful retrieval of natural gas hydrate or hydrate-bearing sediments from remote settings, as well as for temporary low-pressure transport and storage of natural gas.

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FIELD DEMONSTRATION OF CARBON DIOXIDE MISCIBLE FLOODING IN THE LANSING-KANSAS CITY FORMATION, CENTRAL KANSAS

Progress is reported for the period from October 1, 2000 to December 31, 2000. The Carter-Colliver #1 CO2 I was drilled at the end of the last quarter and completed and logged at the beginning of this quarter (Task 2.1). In this quarter analysis was performed on the logs and cores from the Murfin Drilling Company Carter-Colliver #1 CO2 I well. Log and core data from the new Carter-Colliver #1 CO2 I injection well have been collected,  formatted and placed on the website (Task 1.1), and analyzed (Tasks 2.1.2, 2.1.3, 2.1.4). Both logs and core have been analyzed to evaluate residual oil saturation in the reservoir (Task 2.2.1). In addition, routine and advanced core analysis has been performed (Tasks 2.2.3, 2.2.5, and 2.2.6). The available core has been described (task 2.2.7) and all data are being integrated into the existing geomodel of the reservoir.

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Seafloor Collapse and Methane Venting Associated with Gas Hydrate on the Blake Ridge- Causes and Implications to Seafloor Stability and Methane Release

The Blake Ridge, off the southeastern United States, is marked by a large topography depression that is located directly on the ridge crest. The depression is considered to be a collapsed structure that appears to have been formed by gas hydrate-related processes. The mobilization of sediments that was required to produce this collapse probably would have triggered landslides if it took place on a steeper continental slope/rise, so the study of its formation will provide insight regarding the influence of gas hydrate on seafloor instabilities. The large sediment volume-loss associated with formation of the collapse probably transferred a large volume of methane from the sedimentary reservoir to the atmosphere and the process has probably influence the global greenhouse. This paper will consider the structure, causes, relationship to gas hydrate processes, and implications of this feature.

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