AndreaBozzo/ceres-open-data-index huggingface dataset:
Integrated seismic study of naturally fractured tight gas reservoirs. Final report, September 1991--January 1995

The approach in this project has been to integrate the principles of rock physics into a quantitative processing and interpretation scheme that exploits, where possible, the broader spectrum of fracture zone signatures: (1) anomalous compressional and shear wave velocity; (2) Q and velocity dispersion; (3) increased velocity anisotropy; (4) amplitude vs. offset (AVO) response, and (5) variations in frequency content. As part of this the authors have attempted to refine some of the theoretical rock physics tools that should be applied in any field study to link the observed seismic signatures to the physical/geologic description of the fractured rock. The project had 3 key elements: (1) rock physics studies of the anisotropic viscoelastic signatures of fractured rocks, (2) acquisition and processing of seismic reflection field data, and (3) interpretation of seismic and well log data. The study site is in a producing field operated by Amoco and Arco at the southern boundary of the Powder River basin in Wyoming. During the winter of 1992--1993 the authors collected about 50 km of 9-component reflection seismic data and obtained existing log data from several wells in the vicinity. The paper gives background information on laboratory studies, seismic field studies of fracture anisotropy, and the problem of upscaling from the laboratory to the field. It discusses fluid effects on seismic anisotropy and a method for predicting stress-induced seismic anisotropy. Then results from the field experiment are presented and discussed: regional geologic framework and site description; seismic data acquisition; shear wave data and validation; and P-wave data analysis. 106 refs., 52 figs.

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Energy and environmental research emphasizing low-rank coal. Semi-annual report, January--June 1994

Summaries of progress on the following tasks are presented: Mixed waste treatment; Hot water extraction of nonpolar organic pollutant from soils; Aqueous phase thermal oxidation wastewater treatment; Review of results from comprehensive characterization of air toxic emissions from coal-fired power plants; Air toxic fine particulate control; Effectiveness of sorbents for trace elements; Catalyst for utilization of methane in selective catalytic reduction of NOx; Fuel utilization properties; Hot gas cleaning; PFBC; catalytic tar cracking; sulfur forms in coal; resid and bitumen desulfurization; biodesulfurization; diesel fuel desulfurization; stability issues; Sorbent carbon development; Evaluation of carbon products; Stable and supercritical chars; Briquette binders; Carbon molecular sieves; Coal char fuel evaporation canister sorbent; Development of a coal by-product classification protocol for utilization; Use of coal ash in recycled plastics and composite materials; Corrosion of advanced structural materials; Joining of advanced structural materials; Resource data evaluation; and the Usti and Labem (Czech Republic) coal-upgrading program.

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The Nucla Circulating Fluidized-Bed Demonstration Project: A U.S. DOE post-project assessment

This report is a post-project assessment of the Nucla Circulating Fluidized-Bed (CFB) Demonstration Project, the second project to be completed in the DOE Clean Coal Technology Program. Nucla was the first successful utility repowering project in the US, increasing the capacity of the original power station from 36 MW(e) to 110 MW(e) and extending its life by 30 years. In the CFB boiler, combustion and desulfurization both take place in the fluidized bed. Calcium in the sorbent captures sulfur dioxide and the relatively low combustion temperatures limit NOx formation. Hot cyclones separate the larger particles from the gas and recirculates them to the lower zones of the combustion chambers. This continuous circulation of coal char and sorbent particles is the novel feature of CFB technology. This demonstration project significantly advanced the environmental, operational, and economic potential of atmospheric CFB technology, precipitating a large number of orders for atmospheric CFB equipment. By 1994, more than 200 atmospheric CFB boilers have been constructed worldwide. Although at least six CFB units have been operated, the Nucla project`s CFB database continues to be an important and unique resource for the design of yet larger atmospheric CFB systems. The post-project assessment report is an independent DOE appraisal of the success a completed project had in achieving its objectives and aiding in the commercialization of the demonstrated technology. The report also provides an assessment of the expected technical, environmental, and economic performance of the commercial version of the technology as well as an analysis of the commercial market.

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Horizontal CO2 Injection Wells Phillips Project in West Texas

Phillips Petroleum is applying horizontal well technology to inject CO2 in a depleted reservoir in the South Cowden Field, Texas Permian Basin. Typically, horizontal production wells are used to contact more of the reservoir, intersect fractures which may contain oil, or prevent the production of gas from above or water from below a thin oil interval. Phillips plans to show that drilling horizontal CO2 injection wells from a central location will reduce the number and cost of new injection wells, concentrate injection equipment, and minimize the cost of CO2 distribution. Gas injection rates can be higher in horizontal wells because of increased contact with more of the reservoir. However, the quantify of CO2 necessary to maintain a sufficient distribution within the reservoir may actually be lower. This reduces the number of injection wells and the capital costs required to recover additional reserves. For horizontal well application to be successful, there must be a good understanding of the reservoir characteristics and the interaction of CO2 and oil within the reservoir. Optimum locations for the horizontal injectors must be selected and the wells properly completed within the productive interval of the reservoir. Phillips has completed all of the scheduled reservoir studies, and is preparing January 1996) to implement drilling of the horizontal wells and begin injection of CO2 to test the efficiency of the technology. A reservoir model has been developed to integrate the rock, fluid, and seismic data. Laboratory tests are underway to identify surfactants and gelled polymers for control of fluid movement within the reservoir. The size, design, and location of the injection wells are being determined. Project economics are being evaluated.

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Reservoir Efficiency Processes Enhanced Oil Recovery Production Research

The Department of Energy has maintained an active research and development program since its inception in 1918. The program has constantly evolved and adjusted to meet the ever-changing needs of the oil industry. The program has been highly successful and serves today as a vital resource to the nation's research and development program within the oil industry. Private industry, beginning in the 1930?s funded most of the applied research and development activities in the oil industry through the mid-1980s. Most of the major oil companies had research centers and funded major programs for the development of new technologies. These programs resulted in the creation of new technologies that kept the industry strong and competitive. However, the collapse of oil prices in 1986 has resulted in a major restructuring of the industry. The research departments of the major companies have constantly been eroded due to a long period of low oil prices. Today, most of the research departments of the major oil companies no longer exist. This decline in research activity will eventually erode the capabilities of the major companies to compete globally for the discovery and production of oil. DOE?s role in the research and development of enhanced oil recovery (EOR) technology has become increasingly important as the industry research activity has continued to decline. DOE?s role is expected to become even more vital as the country becomes ever more dependent upon insecure sources of foreign oil. The expertise maintained within DOE and through contractors is needed to maintain a healthy oil and gas industry within the United States and to protect the vital interests of the country. The purpose of this report is to address issues raised by the National Research Council in the review of DOE activities. The report addresses these specific issues, describes the various EOR technologies, and discusses the benefits of the program that have been accomplished over the years.

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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. In the second phase of this project, the model will be used for the design of a pilot program for downhole water re-injection into the aquifer simultaneously with oil production. Downhole water separation units attached to electric submersible pumps will be used to minimize surface fluid handling thereby improving recoveries per well and field economics while maintaining aquifer support.

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Assessing and Forecasting, by Play, Natural Gas Ultimate Recovery Growth and Quantifying the Role of Technology Advancements in the Texas Gulf Coast Basin and East Texas

A detailed natural gas ultimate recovery growth (URG) analysis of the Texas Gulf Coast Basin and East Texas has been undertaken. The key to such analysis was determined to be the disaggregation of the resource base to the play level. A play is defined as a conceptual geologic unit having one or more reservoirs that can be genetically related on the basis of depositional origin of the reservoir, structural or trap style, source rocks and hydrocarbon generation, migration mechanism, seals for entrapment, and type of hydrocarbon produced. Plays are the geologically homogeneous subdivision of the universe of petroleum pools within a basin. Therefore, individual plays have unique geological features that can be used as a conceptual model that incorporates geologic processes and depositional environments to explain the distribution of petroleum.

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Assessment of Air Emissions at the U S Liquids Exploration and Production Land Treatment Facility

This project was initiated to make the first set of measurements documenting the potential for emissions of pollutants from exploration and production (E&P) waste disposal facilities at Bourg, Louisiana and Bateman Island, Louisiana. The objective of the project was to quantify the emissions and to determine whether the measured emissions were potentially harmful to human health of workers and the adjacent community. The study, funded by the Department of Energy (DOE) is designed to complement additional studies funded by Louisiana Department of Natural Resources (LADNR) and the American Petroleum Institute (API). The distinguishing feature of this study is that actual, independent field measurements of emissions were used to assess the potential problems of this disposal technology.

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High-Resolution Reservoir Characterization Using Seismic, Well, and Dynamic Data

Prediction of fluid production based on static reservoir models often fails to match the observed field production history. For reliable future performance predictions, it is imperative that the reservoir models adequately reproduce the past performance history of the reservoir and for this, it is necessary to condition the static model with dynamic reservoir data, such as transient pressure, tracer response and multiphase production history. Integration of dynamic data can be particularly effective in identifying preferential flow paths or barriers to flow that can adversely impact sweep efficiency. Identification of the location and distribution of these barriers is critical to the success of the secondary and tertiary recovery efforts. Integration of production data in conventional finite-difference simulators is computationally infeasible for the large number of simulations involved and has never been done in a fine-scale reservoir model consisting of millions of grid blocks. Lawrence Berkeley National Laboratory and Texas A & M University have, for the first time, adopted a very flexible and efficient approach to merge different data types (production, seismic, well log) by developing a very general and computationally efficient 3D streamline simulator for modeling multiphase flow through fine-scale reservoir models. Besides being cost-effective, the streamline based flow simulator is computationally efficient in rapid inversion of dynamic production data by using an analogy between the streamlines and ray tracing in seismology. This allows application of efficient inversion technology from seismic for integration of production data. The algorithm developed has reduced the time required to invert tracer data for 3D reservoir structure in an entire field by about 10-1000 times. The feasibility of the approach developed has been demonstrated in field applications in the carbonate reservoirs at the North Robertson Unit and the Goldsmith San Andres Unit in West Texas. The new reservoir characterization technology will lead to efficient management of a wide variety of oil and gas reservoirs by identifying bypassed oil/gas for targeting infill drilling, extending life of wells by reducing early water breakthrough and reducing water cycling and enhancing sweep efficiency. Enhanced production of even 1/2% of oil and gas from already discovered reserves by this technology will result in additional production of 400 MMBLS of oil and 26 Tcf of natural gas. This production will generate 17 billion dollars of income for the Federal government in the form of taxes and royalties and will create 9,000 new jobs in various sectors.

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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 April 1, 2001 to June 30, 2001. Assessment of the demonstration site has defined many aspects of the reservoir. However, uncertainty in reservoir permeability distribution and residual oil saturation is sufficiently great that assuring viability of the project warrants further reservoir characterization. Economic and recovery analysis of the Colliver lease, based on the existing reservoir model, indicates that a lease pattern of 60-acres provides the oil production revenues and CO2 usage needed for the demonstration to be economically viable for MV Energy LLC and ICM Inc

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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 April 1, 2001 to June 30, 2001. Assessment of the demonstration site has defined many aspects of the reservoir. However, uncertainty in reservoir permeability distribution and residual oil saturation is sufficiently great that assuring viability of the project warrants further reservoir characterization. Economic and recovery analysis of the Colliver lease, based on the existing reservoir model, indicates that a lease pattern of 60-acres provides the oil production revenues and CO2 usage needed for the demonstration to be economically viable for MV Energy LLC and ICM Inc.

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Subsurface Contaminant Focus Area: Monitored Natural Attenuation (MNA) ? Programmatic, Technical, and Regulatory Issues

Natural attenuation processes are commonly used for remediation of contaminated sites. A variety of natural processes occur without human intervention at all sites at varying rates and degrees of effectiveness to attenuate (i.e., decrease) the mass, toxicity, mobility, volume, or concentrations of organic and inorganic contaminants in soil, groundwater, and surface water systems. As defined in the U.S. Environmental Protection Agency (EPA) policy for monitored natural attenuation as a remediation alternative, these in situ, natural attenuation processes include biodegradation; dispersion; dilution; sorption; volatilization; radioactive decay; and chemical or biological stabilization, transformation, or destruction of contaminants. The major driver for using this approach for site remediation is the perception that monitored natural attenuation will be simpler and less costly to implement as compared to using active remediation technologies. However, this cost argument is not valid when considering all requirements described in EPA?s regulatory and technical guidance for monitored natural attenuation.

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Gas Hydrate in Seafloor Sediments: Impact on Future Resources and Drilling Safety

Gas hydrate concentrates methane and sometimes other gases in its crystal lattice and this gas can be released intentionally creating a resource or escape accidentally forming a hazard. The densest accumulations of gas hydrate tend to occur at sites where the base of the gas hydrate stability zone is configured to trap gas, often as a broad arch. The gas may rise from below or form by pacterioal activity at shallow depth, but gas commonly is concentrated near the base of the gas hydrate stability zone by recycling. This gas accumulates in presumably leaky traps, then enriches the hydrate above as it migrates upward by diffusion, fluid movement through sedimentary pores, or flow along fracture channel ways. Analysis of seismic reflection profiles is beginning to identify such concentrations and the circumstances that create them.

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Basin Analysis of the Mississippi Interior Salt Basin and Petroleum System Modeling of the Jurassic Smackover Formation, Eastern Gulf Coastal Plain

Part 3 (Petroleum System Modeling of the Jurassic Smackover Formation) objectives are to provide an analysis of the Smackover petroleum system in Years 4 and 5 of the project and to transfer effectively the research results to producers through workshops and topical reports.

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Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of CO2 Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales

During the 2nd quarter of 2001, C02 injection was suspended in early May 2001 as the project continues to be hampered by excessive sanding of the producers. Five wells had to be shut-in for remedial procedures: ll-SD, ll-SE, 12-SB, 12-SC, and 12-SD. It appears that the CO2 injection has played a role in the sanding problems. As a result, we reverted back to water injection in the four pilot injectors (ll-SWR, ll-SWAR, 12-7W, and 12-SW). The plan is now to chemically treat the 5 problem producers in mid July 2001 to address sand control and return to CO2 injection in early August 200 1. The following is a summary of the CO2 pilot execution that occurred during the 2nd quarter of200l.

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Increasing Waterflood Reserves in the Wilmington Oil Field Through Improved Reservoir Characterization and Reservoir Management

In 1994 Pacific Operators Offshore, Inc. sought and won a United States Department of Energy Class III cost sharing project to perform reservoir studies leading to the drilling of a trilateral redevelopment well in their Carpinteria Offshore Field in the Santa Barbara Channel of California. The intent of the project was to increase production and extend the economic life of this mature field through the application of advanced reservoir characterization and drilling technology, demonstrating the efficacy of these technologies to other small operators of aging fields. Two study periods were proposed; the first to include data assimilation and reservoir characterization and the second to drill the demonstration well. The initial study period showed that a single tri lateral well would not be economically efficient in redevelopment of Carpinteria's multiple deep water turbidite sand reservoirs, and the study was amended to include the drilling of a series of horizontal redrills from existing surplus well bores on Pacific Operators'Platform Hogan. After some 42 months of study, during which all existing field data were digitized, wells were re-related elated, digital petrophysical studies were performed, fault blocks defined and reservoir geometries identified and mapped, and redevelopment targets identified and graded, four target zones in two fault blocks were selected for initial redevelopment. Two pilot wells were drilled in the selected fault blocks to verify adequate remaining oil saturation, resulting in the re-assessment of one of the target zones. For economic efficiency, these wells were completed as conventional infill producers. Immediately following, drilling was commenced on the four horizontal wells. Each was completed in its target zone using slotted liner. Producing intervals averaged around 500 feet in length. In total, the initial redevelopment project added 760 barrels per day, dramatically increasing the production from Platform Hogan and extending the economic life of the field.

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Madden Deep Unit Madison Wells Fremont County Wyoming Challenges & Wish List

Deep --  /- 25,000? --  /- one year to drill  Large holes required for casing strings  Crooked hole potential shallow to  /-12,000 Hole stability issues with improper drilling fluids Fast drilling in large hole size requiring good hydraulics  Slow hard drilling from 10,000 to TD Tight hole clearances for casing strings Overpressured and depleted formations from 5,000 to 24,000 Heavy casing strings 2 strings over 1MM lbs -Special rolling of most casing strings -Hot --  430oF BHST -Corrosive gases in the production stream --  12% H2S  20% CO2

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Basin Analysis of the Mississippi Interior Salt Basin and Petroleum System Modeling of the Jurassic Smackover Formation, Eastern Gulf Coastal Plain

Part 3 (Petroleum System Modeling of the Jurassic Smackover Formation) objectives are to provide an analysis of the Smackover petroleum system in Years 4 and 5 of the project and to transfer effectively the research results to producers through workshops and topical report.

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