AndreaBozzo/ceres-open-data-index huggingface dataset:
Chronostratigraphic hydrocarbon plays and depositional styles in the northern Gulf of Mexico

Sand-body reservoirs in the Federal OCS of the northern Gulf of Mexico were classified into 98 chronostratigraphic plays by style, structural style, and engineering parameters. Cumulative gas production is apportioned to three primary depositional styles: progradational (65%), submarine fan (16%), and aggradational (12%). In contrast, cumulative oil production is distributed primarily as progradational (58%), aggradational (23%), and submarine fan (16%). On the continental shelf, progradational environments are hydrocarbon rich owing to favorable sandstone-to-shale ratios and traps over salt structures and faulted anticlines. Submarine fan plays dominate downdip of the modern shelf edge. Remaining recoverable gas reserves for progradational (48%), submarine fan (28%), and aggradational (16%) reveal a decline of progradational plays and an increase of submarine fan plays. Average porosity varies between fan plays (26%), progradational plays (29%), and aggradational or retrogradational plays (28%) (statistical significance, 85% to 98%), in part as a function of play depth, which is greatest for submarine fan plays (11,631 ft). Average pay thickness of fan (45 ft) and retrogradational (34 ft) plays is higher than that of aggradational and progradational plays (31 ft) (statistical significance, 85% to 99%). Proved hydrocarbons are unequally distributed within chronozones in the Gulf. Forty-two percent of the original recoverable oil is concentrated in two chronozones-the lower Pleistocene Lenticulina 1 to Buliminella 1 (22.8%) and the upper Miocene Bigeneria A to Cristellaria K (20.4%). Gas is more uniformly distributed. Of the original recoverable gas, 29% exists in two chronozones-the lower Pleistocene Lenticulina 1 to Valvulina H (18.6%) and the upper Pleistocene Hyalinea balithica to Sangamon (10.6%). New discoveries will probably be made in submarine fan plays in Pleistocene to Miocene strata on the slope and in Miocene and older fan facies on the shelf.

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Environmental management technology demonstration and commercialization: Tasks 2, 3, 4, and 8. Semiannual report, October 1994--March 1995

The objective of the Environmental Management program at the Energy and Environmental Research Center (EERC) is to develop, demonstrate, and commercialize technologies that address the environmental management needs of contaminated sites, including characterization, sensors, and monitoring; low-level mixed waste processing; material disposition technology; improved waste forms; in situ containment and remediation; and efficient separation technologies for radioactive wastes. Task 2 is the extraction and analysis of pollutant organics from contaminated solids using off-line supercritical fluid extraction (SFE) and on-line SFE-infrared spectroscopy. Task 3, pyrolysis of plastics, has as its objectives to develop a commercial process to significantly reduce the volume of mixed-plastics-paper-resin waste contaminated with low-level radioactive material; concentrate contaminants in a collectible form; and determine the distribution and form of contaminants after pyrolysis of the mixed waste. Task 4, stabilization of vitrified wastes, has as its objectives to (1) demonstrate a waste vitrification procedure for enhanced stabilization of waste materials and (2) develop a testing protocol to understand the long-term leaching behavior of the stabilized waste form. The primary objective of Task 8, Management and reporting, is coordination of this project with other programs and opportunities. In addition, management oversight will be maintained to ensure that tasks are completed and coordinated as planned and that deliverables are submitted in a timely manner. Accomplishments to date is each task are described. 62 refs.

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High-volume, high-value usage of Flue Gas Desulfurization (FGD) by-products in underground mines. Phase 1 -- Laboratory Investigations. Quarterly report, January 1995--March 1995

The study of the kinetics of the mineral transformations which take place after the FGD materials are hydrated was continued this quarter (Task 2, Subtask 2.2). Based on X-ray diffraction data, the anhydrite was found to have essentially disappeared by the fifth day of the study, while gypsum was found to maximize in the first 14 days of the study. The relative abundance of ettringite increased throughout the period of observation (40 days). Ettringite was found to nucleate primarily on or near fly ash particles, while gypsum was found to be more mobile, readily filling in cracks and fractures. A second kinetic study was initiated during the period with an experimental setup which is similar to the current effort. The focus of this study will be to determine the effect of moisture conditions on the rate and types of mineralogical reactions which occur. Column leaching studies (Task 2, Subtask 2.4) on the ADM material were initiated during the quarter. Two columns were packed with fly ash and one with bottom ash. One of the columns was blanketed with CO{sub 2} (2.5%) to model the effects of soil gas on the leachate. The samples are being moisturized to model field conditions. Leachate analysis will be available during the next quarter. Work on the field site (Task 6) to establish background data for the demonstration continued. The proposed demonstration site at the Pleasant Valley mine was found to be displaying the effects of severe weathering. An alternate mine site will be explored.

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Field-usable portable analyzer for chlorinated organic compounds. Topical report, September 1992--May 1994

Through a U.S. DOE-funded program, an advanced chlorinated organic (RCL) vapor monitor has been built and tested in actual hazardous waste site operations. The monitor exploits the analytical capabilities of a solid-state sensor which was recently developed and has remarkable selectivity for chlorinated organic vapors at sub-parts-per-million sensitivity. The basic design goal of a user-friendly, reliable, instrument with a broad dynamic range for the selective detection of chlorinated solvent vapors was demonstrated. To date, no non-halogen-containing compound has been identified that induces a measurable response on the sensor, including commonly encountered contaminants such as BTXs (benzene, toluene, and xylenes) or POLs (petroleum, oils, lubricants). In addition to the development of the RCL MONITOR, advanced sampler systems were developed to further extend the analytical capability of this instrument, allowing chemical analyses to be performed for both vapor phase and condensed contamination. The sampling methods include fixed dilution, preconcentration, and closed-loop air stripping for condensed media. With uniform success, these different series of field tests were conducted at DOE facilities on several types of samples. Independent cost-benefit analysis has concluded that significant cost savings can be achieved using the RCL MONITOR in DOE applications. This effort provides a sound fundamental technology base for the development of advanced analytical methods that are needed by the US DOE. In addition, advanced methods for detecting chlorinated hydrocarbons that are made possible by this technology will save time, reduce costs, and improve human health and safety in restoration operations. To fully achieve all possible cost savings, continued effort is necessary to develop validated methods for the use of the RCL MONITOR. The development of methods through case studies is the theme of the Phase II effort, which is currently underway.

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APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF CARBONATE 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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Discrete Feature Approach for Heterogeneous Reservoir Production Enhancement/Fundamental Geoscience Award

In heterogeneous reservoirs where discrete features such as fractures, faults and discontinuous sand distribution play a significant role in permeability, the ultimate recovery can be as low as 10% of the estimated oil-in-place (OIP). The unrecovered in such reservoirs constitutes a significant potential resource for the mature petroleum industry in the United States. In conventional reservoir engineering, simplifying assumptions are made, based on a "layer cake "continuum concept that fails when discrete features control flow at the well scale, or networks of discrete features cont flow at the interwell scale. In this project, the Golder Associates team developed and demonstrated the use of discrete feature network (DFN) models as the key tool for integrating geological, geophysical and engineering data from a wide range of scales t improve reservoir development and increase oil production efficiency. The key issues addressed by the new technology are: placement of injection and production wells that could determine production efficiency, development of enhanced completion connection between well completion and the discrete reservoir flow network and development in gel treatment to effectively seal the fractures and improve reservoir sweep efficiency. The usefulness of DFN approach in IOR applications was demonstrated in four producing fields by first developing DFN models of discrete features in the reservoirs from reservoir data and then extrapolating the features using a combination of geological and geostatistical methods. Preliminary data indicate that the application of DFN approach to surfactant injection in Yates field resulted in enhanced oil production of 36,300 barrels and the gel treatment in South Oregon field yielded 10 BOPD from each well. The DFN technology is directly applicable to a large percentage of the secondary and tertiary oil recovery projects currently underway in the United States, and could be of significant value in the design of future oil recovery projects. The new approach should DE-AC26-98BC15101 1 be applicable to a wide range of heterogeneous reservoirs, the most important of which are the fractured carbonate reservoirs that account for 20% of total oil production within the United States and abroad. On a conservative estimate, the successful application of this approach should help to add at least 182 million barrels of oil 1.77 TCF of natural gas to the national reserves. Development of these resources should generate 288 and 941 million dollars in tax and royalty incomes and create 1082 new jobs in all sectors of the national economy

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Identifying Oil Exploration Leads Using Integrated Remote Sensing and Seismic Data Analysis, Lake Sakakawea, Fort Berthold Indian Reservation, Williston Basin

DOE solicitation for projects to develop oil reserves on non-allotted Native American Lands. -ARI?s desire to demonstrate its remote sensing exploration technology in oil shale reservoirs (e.g., Mancos, Bakken, etc.). -Three Affiliated Tribes favorable location in the Williston Basin and availability of large tract of (150,000 acres) unleased non-allotted Tribal Lands.

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An Integrated Approach to Characterization Bypassed Oil Saturation in Heterogeneous & Fractured Reservoirs Using Tracers

The goal of this project is to develop a systematic and cost-effective approach to the design and interpretation of Partitioning Interwell Tracer Tests (PITT) to infer hydrocarbon saturation distribution in highly heterogeneous and fractured reservoirs. The key elements of our approach are a very fast streamline-based flow simulation technique and a rapid and novel history matching technique that exploits an analogy between streamlines and seismic ray tracing. Our approach will be orders of magnitude faster than conventional history matching, resulting in significant savings in computation time and manpower. The integrated approach will take advantage of the dense spatial coverage of the seismic data for static modeling and the strong coupling of interwell saturation variations to partitioning tracer response. The outcome of this research will be a systematic approach to the design and interpretation of tracer data and practical, PC-based, software tools providing high-resolution saturation estimates in the interwell region by combining well log, seismic, and partitioning tracer data.

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

Feasibility of alkaline-surfactant-polymer flood for the Lawrence Field in Lawrence County, Illinois is being studied. Two injected formulations are being designed; one for the Bridgeport A and Bridgeport B reservoirs and one for Cypress and Paint Creek reservoirs. Fluid-fluid and coreflood evaluations have developed a chemical solution that produces incremental oil in the laboratory from the Cypress and Paint Creek reservoirs. A chemical formulation for the Bridgeport A and Bridgeport B reservoirs is being developed. A reservoir characterization study is being done on the Bridgeport A, B, & D sandstones, and on the Cypress sandstone. The study covers the pilot flood area and the Lawrence Field.

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APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF CARBONATE 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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New Insights into the Phenomenon of Anomalous or ?Self? Preservation of Gas Hydrates

We previously reported on a thermal regime where pure, polycrystalline methane hydrate is preserved metastably in bulk at up to 75 K above its nominal temperature stability limit of 193 K at 1 atm, following rapid release of the sample pore pressure. Large fractions (> 50 vol. %) of methane hydrate can be preserved for 2-3 weeks by this method, reflecting the greatly suppressed rates of dissociation that characterize this ?anomalous preservation? regime between 242 to 271 K. This behavior contrasts that exhibited by methane hydrate at both colder (193?240 K) and warmer (272?290 K) isothermal test conditions, where dissociation rates increase monotonically with increasing temperature. Here, we report on recent experiments that revisit the curious variation of dissociation rates within the anomalous preservation regime, most notably between 255 and 265 K where rates are greater than those at closely bracketing temperatures. Temperature-stepping experiments corroborate the relative rates measured previously in isothermal preservation tests, and also reveal the remarkably reproducible temperature sensitivity of the preservation effect in this thermal regime. These results, coupled with SEM imaging of quenched sample material from anomalous preservation tests, strongly support our earlier arguments that ice ?shielding? effects provided by partial dissociation along hydrate grain surfaces are not the primary mechanism for anomalous preservation. Furthermore, sII methane-ethane hydrate was found to exhibit no comparable preservation effect when rapidly depressurized at 268 K, even though it is thermodynamically stable to higher temperatures and lower pressures than sI methane hydrate. The underlying physical chemistry mechanisms of anomalous preservation remain elusive, but appear to be based more on textural or morphological changes within the hydrate material itself, rather than on compositional zoning or ice-rind development.

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Application of Reservoir Characterization and Advanced Technology to Improve Recovery and Economics in a Lower Quality Shallow Shelf Carbonate  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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Stratigraphic Equivalents of the Wilmington Field "Tar Zone"  in the Subsurface Los Angeles Basin, California

A seven-year thermal project in "old Wilmington" field (Los Angeles basin) for the "Tar zone" is part of a technology-transfer program by the United States Department of Energy (U.S. DOE) which proposes to transfer successful new techniques to other oil and gas producers operating reservoirs comprised by sediments exhibiting similar conditions of heterogeneity and depositional environment. The present form and structural relief of the Los Angeles basin were established during late Miocene time. Most of the area consisted of marine slope-to-basin environments during late Miocene and early Pliocene time. The basin is divided into four structural blocks with major zones of faulting in the basement rocks at the contacts between blocks. The fault systems bounding the blocks have allowed each block to have a different subsidence history and basement configuration.

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Class Revisit Oil Recovery Projects Table of Contents

The Eva South Morrow Sand Unit is located in western Texas County, Oklahoma. The field produces from an upper Morrow sandstone, termed the Eva sandstone, deposited in a transgressive valley-fill sequence. The field is defined as a combination structural stratigraphic trap; the reservoir lies in a convex up -dip bend in the valley and is truncated on the west side by the Teepee Creek fault. Although the field has been a successful waterflood since 1993, reservoir heterogeneity and compartmentalization has impeded overall sweep efficiency. A 4.25 square mile high-resolution, three component three-dimensional (3C3D) seismic survey was acquired in order to improve reservoir characterization and pinpoint the optimal location of a new horizontal producing well, the ESU 13-H.  Extensive modeling was conducted prior to seismic acquisition to predict the seismic response and define acquisition parameters. Although the seismic did not define any new undeveloped reservoir compartments, the P-wave data was successful in providing excellent detail of the structural configuration of the field and adequate resolution of reservoir extents and geometry. The PSV converted-wave data appears to have defined reservoir extents and geometry, although with a probable overprint from acquisition geometry and principle stress fields. In general, the P-wave data proved to be a valuable exploration and development tool, though not capable of defining all reservoir complexities for detailed reservoir engineering. The PSV converted-wave data showed promise for future applications of this evolving technology. The seismic data were utilized to locate the ESU 13-H horizontal well parallel to, and within 200 feet of the Teepee Creek fault in an area thought to contain additional reserves. The reservoir development was as expected, although only approximately 1000 feet of the planned 2800 feet of horizontal drilling was achieved prior to the well becoming permanently stuck. Despite this setback, the well was successful in adding 122 MBO of incremental reserves, representing 1.7% of the original oil in place (OOIP) in the field; targeted incremental reserves were 150 MBO, or 2.0% of the OOIP.  Conclusions are that high-resolution 3C3D seismic and horizontal wells are effective tools for improving reservoir characterization and sweep efficiency in Morrow and other (DOE) Class 1 reservoirs.

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Issues, R&D Needs, and Potential Actions for DOE's R&D Program Activities in Produced Water and Air Quality Management

The DOE Oil and Gas Environmental Research and Analysis Program has the mission to "promote cost-effective environmental protection and enhance environmental performance to encourage maximum recovery of U. S. oil and gas resources." New, comprehensive initiatives in produced water and air quality are being planned and initial procurements are being prepared to carry out this mission. To assist in this planning, DOE commissioned a highly expedited effort to capture and synthesize the views of experts and stakeholders as to R&D objectives, resource requirements, timing and priorities.

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