AndreaBozzo/ceres-open-data-index huggingface dataset:
Improving CO2 Efficiency for Recovering Oil in Heterogeneous Reservoirs

The second annual report of "Improving CO2 Efficiency for Recovery Oil in Heterogeneous Reservoirs" presents results of laboratory studies with related analytical models for improved oil recovery. All studies have been undertaken with the intention to optimize utilization and extend the practice of CO2 flooding to a wider range of reservoirs. Many items presented in this report are applicable to other interest areas: e.g. gas injection and production, greenhouse gas sequestration, chemical flooding, reservoir damage, etc. Major areas of studies include reduction of CO2 mobility to improve conformance, determining and understanding injectivity changes in particular injectivity loses, and modeling process mechanisms determined in the first two areas. Interfacial tension (IFT) between a high-pressure, high-temperature CO2 and brine/surfactant and foam stability are used to assess and screen surfactant systems. In this work the effects of salinity, pressure, temperature, surfactant concentration, and the presence of oil on IFT and CO2 foam stability were determined on the surfactant (CD1045TM). Temperature, pressure, and surfactant concentration effected both IFT and foam stability while oil destabilized the foam, but did not destroy it. Calcium lignosulfonate (CLS) can be used as a sacrificial and an enhancing agent. This work indicates that on Berea sandstone CLS concentration, brine salinity, and temperature are dominant affects on both adsorption and desorption and that adsorption is not totally reversible. Additionally, CLS adsorption was tested on five minerals common to oil reservoirs; it was found that CLS concentration, salinity, temperature, and mineral type had significant effects on adsorption. The adsorption density from most to least was: bentonite > kaolinite > dolomite > calcite > silica. This work demonstrates the extent of dissolution and precipitation from co-injection of CO2 and brine in limestone core. Metal tracers in the brine were used as markers to identify precipitation location and extent. This indicated possible causes of permanent permeability changes in the core and thus in a reservoir. Core segment porosity, permeability, chemical and back-scattered electron imaging, and chemical titrations were all used for qualitative and quantitative determination of compositional and injectivity changes. Also, injectivity effects of high flow rate near a wellbore and stress changes were shown on five different cores (two Berea sandstones, two Indiana limestones, and one Dakota sandstone).

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Neutron powder diffraction studies as a function of temperature of structure II hydrate formed from propane

Neutron powder diffraction data confirm that hydrate samples synthesized with propane crystallize as structure type II hydrate. The structure has been modeled using rigid-body constraints to describe C3H8 molecules located in the eight larger polyhedral cavities of a deuterated host lattice. Data were collected at 12, 40, 100, 130, 160, 190, 220, and 250 K and used to calculate the thermal expansivity from the temperature dependence of the lattice parameters. The data collected allowed for full structural refinement of atomic coordinates and the atomic-displacement parameters.

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YOU SEE ICE -WE SEE GAS HYDRATES

What happens when you take a high-technology, medical computed tomography (CT) system, remove 80 percent of the weight, shrink it to the size of a refrigerator, increase its imaging resolution, cut the cost by an order of magnitude, and optimize it to look at geologic core samples? What you end up with may look like the world's first cabinet-safe, portable, x-ray CT, wholecore scanner built by engineers and scientists at Lawrence Berkeley National Laboratory (Berkeley Lab).

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Development of New Types of Non-Damaging Drill-in and Completion Fluid

The goal of the project has been to develop new types of drill-in fluids (DIFs) and completion fluids (CFs) for use in natural gas reservoirs. Phase 1 of the project was a 24-month study to develop the concept of advanced type of fluids usable in well completions. Phase 1 tested this concept and created a kinetic mathematical model to accurately track the fluid's behavior under downhole conditions. Phase 2 includes tests of the new materials and practices. Work includes the preparation of new materials and the deployment of the new fluids and new practices to the field.

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Cruise Report for G1-03-GM USGS Gas Hydrates Cruise, R/V Gyre, 1-14 May, 2003, Northern Gulf of Mexico

This report gives a summary of the field program and instrumentation used on the R/V Gyre in the Gulf of Mexico in May, 2003 to collect multichannel seismic data in support of USGS and Department of Energy gas hydrate studies. Tabulated statistics, metadata, figures and maps are included to show the breadth of data collected and preliminary interpretations made during the field program.

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Gas Hydrate in the Northern Gulf of Mexico: New Insights Learned from Giant Piston Coring

The northern Gulf of Mexico hosts numerous seafloor (<7m subbottom) occurrences of gas hydrate. The seafloor is dominated by salt-tectonic basin structures, high sedimentation rates (about 40 cm/yr), and complex late Neogene stratigraphy with common seafloor failures. Natural oil and gas seeps are abundant, usually associated with fault conduits resulting in numerous hydrocarbon vents, often capped by gas hydrate when the seeps are within the hydrate stability zone.

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Carbon Capture and Storage: A Regulatory Framework for States

The prospect of global climate change fueled by the increase of carbon dioxide in the Earth's atmosphere ? attributed by many climate scientists to the activities of man ? has mobilized governments worldwide, including the United States, to examine ways to decrease the emission of carbon dioxide to our atmosphere from anthropogenic sources. One promising option is through carbon capture and geological storage (CCGS) ? capturing carbon dioxide (CO2) before it is released into the atmosphere and storing it in underground geologic formations.

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MULTICOMPONENT SEISMIC ANALYSIS AND CALIBRATION TO IMPROVE RECOVERY FROM ALGAL MOUNDS: APPLICATION TO THE  ROADRUNNER/TOWAOC AREA OF THE PARADOX BASIN, UTE MOUNTAIN UTE RESERVATION, COLORADO

This report describes the results made in fulfillment of contract DE-FG26-02NT15451, ?Multicomponent Seismic Analysis and Calibration to Improve Recovery from Algal Mounds: Application to the Roadrunner/Towaoc Area of the Paradox Basin, Ute Mountain Ute Reservation, Colorado?, for the Fourth Biennial Report covering the time period May 1, 2004 through October 31, 2004.

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Use of Wetland Plant Species and Communities for Phytoremediation of Coalbed Methane Product Water and Waters of Quality Similar to that Associated with Coal bed Methane Deposits of the Powder River Basin

Within the past decade, methane (i.e., a component of natural gas) extraction from water-saturated coal seams has become a significant source of U.S. domestic energy supplies. This process, now commonly referred to as coalbed methane (CBM) or coalbed natural gas extraction, has seen rapid development in the Powder River Basin of Wyoming and Montana in the past decade. Estimates of the amount of methane gas and the number of gas-producing wells in the Powder River Basin vary, depending on source and date of estimate. According to the U. S. Geological Survey, the amount of recoverable CBM from the Powder River Basin ranges from 8.24 to 22.42 trillion cubic feet of gas (USGS, 2001). The Wyoming Oil and Gas Conservation Commission estimates 31 .8 trillion cubic feet of recoverable CBM in the Powder River Basin of Wyoming alone (WY Oil and Gas Conservation Commission, 2002). The Montana Bureau of Mines and Geology and the US. Department of Energy have separately estimated between 0.8 - 1.0 trillion cubic feet of recoverable CBM in the Powder River Basin of Montana. A January 2003 Environmental Impact Statement for coal bed methane development in the Powder River Basin of Montana, jointly prepared by the US. Department of lnterior-Bureau of Land Management and the state of Montana Department of Environmental Quality and Board of Oil and Gas Conservation reports 2.5 trillion cubic feet of recoverable gas within the Powder River Basin.

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Very High-Speed Drill String Communications Network - Intellipipe?

The goal is to lower the cost and improve the efficiency of drilling by increasing the speed and enhancing the reliability of data transmission between the bottom of the drill string and the surface. The objective is to further develop, refine, and commercialize a very high-speed method for transmitting data between the bottom of a drill string and the surface. This utilizes a unique method for transmitting data across a threaded tool joint.

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Scanning Electron Microscope Imaging of Grain Structure and Phase Distribution within Gas-Hydrate-Bearing Intervals from JAPEX/JNOC/GSC et al Mallik 5L-38:  What  Can We Learn From Comparisons With Laboratory-Synthesized Samples?

Cryogenic scanning electron microscopy provides an excellent means for examining phase distributions, grain morphologies, and grain contacts within gas-hydrate-bearing samples of both natural and laboratory origin. Here, recovered samples from JAPEX/JNOC/GSC et al. Mallik 5L-38 are imaged, and comparisons are made between the geometrical arrangement and appearance of the gas hydrate  /- ice phase and arrangements, grain contacts, and textures displayed by pure gas hydrate and gas hydrate-sediment aggregates grown and tested in the laboratory. Many gas hydrate  /- ice sections in Mallik samples occur as smooth, dense material surrounding isolated macropores, whereas other closely juxtaposed sections display highly mesoporous textures. The possible origins of the mesoporosity are evaluated, and likewise the origin of ice mixed with the gas hydrate, both of which influence interpretations of physical-property measurements. Lastly, the authors image lab-synthesized methane hydrate-quartz aggregates using phase proportions comparable to those displayed by Mallik material from sand intervals, and discuss the implications of strength measurements made on the synthetic samples.

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A Guide to Practical Management of Produced Water from Onshore Oil and Gas Operations in the United States

A white paper studying the applicability of various water reduction techniques to the coalbed natural gas development of the Powder River Basin in Montana and Wyoming was prepared as part of a research project funded by the National Energy Technology Laboratory (NETL) of the DOE. This section presents a summary of the findings of this research as they may apply to various basins across the United States.

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Advanced Reservoir Imaging Using Frequency-Dependent Seismic Attributes

Objectives of the Project: -Develop seismic-based technology that correlates and/or quantifies a reservoir's fluid-saturation properties and their spatial distribution to frequency-and angle-dependent reflectivity.  -Project involves theory and processing-algorithm development, numerical and physical modeling, laboratory experiments, and field verification using seismic, well-log, and engineering data.  -Develop extensions to wave-equation models with fluid-flow attenuation and target-oriented seismic processing are two major theoretical developments.

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The Use of Acid Stimulation for Restoring to Production Shut-in Oil Fields

High operating costs and low oil prices caused oil and gas production from the St. James lease to be shut in early 1998. The St. James lease is located in the Las Cienegas field in an historic area of Los Angeles California approximately two (2) miles from the downtown Civic Center. The principal goal of this DOE project is to show how long-term shut-in oil and gas wells can be returned to profitable operation. This goal is aided by improved oil and gas prices and the use of modern stimulation technology. Low oil and gas prices in 1998-1999 led to thousands of oil wells being shut-in throughout the United States. Based upon the premise that oil and gas prices will remain relatively stable in the future, revitalizing shut-in oil and gas wells is now an attractive option for many operators. The effort and expense required to return a shut-in well to production depends, to a large extent, on its condition at the time of shut-in and the efforts taken to preserve the well's productivity while it was shut-in. Obviously, if a well was shut-in because of an equipment failure (tubing leak, pump failure, etc.), the mechanical problem must be corrected first. However, wells with no obvious problem at the time of shut-in other than poor economics ,most likely have developed problems during the shut-in period. St. James? experience has indicted that wells in the Las Cienegas field, which have been shut-in for a long period of time, in this case more than seven (7) years and are returned to production often produce at a rate of 30-50% less than prior rates. Scale deposition caused by filtrate invasion has been found to be the major damage mechanism. Other production-impairment mechanisms are believed to be fines migration and clay dispersion and swelling.

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Improved Miscible Nitrogen Flood Performance Utilizing Advanced Reservoir Characterization and Horizontal Laterals in a Class I Reservoir ? East Binger (Marchand) Unit

The DOE-sponsored project at the East Binger Unit is an investigation into the benefits of reservoir characterization and horizontal wells in this particular setting of geologic and recovery method. The geologic setting is a tight (average porosity of 7% and average permeability of less than 1 millidarcy) Pennsylvanian-age sandstone at about 10,000 feet, and the recovery method is a miscible nitrogen flood

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Field Demonstration of Carbon Dioxide Miscible Flooding in the Lansing-Kansas City Formation, Central Kansas

It is requested that DOE approve continuation into Budget Period 2 (BP2) of the Kansas CO2 flood project, DOE Project No. DE-AC26-00BC15124 entitled ?Field Demonstration of Carbon Dioxide Miscible Flooding in the Lansing-Kansas City Formation, Central Kansas? awarded to the University of Kansas Center for Research, Inc. Budget Period 1 ends on February 7, 2004, we request the continuation take place effective at the end of Budget Period 1 on February 8, 2004. We also request, as per the original proposal, that G. Paul Willhite replace Alan P. Byrnes as Project Manager. This application comprises three sections: A) Project Evaluation Report, B) Budget Period 2 Project Plan, and C) Budget Period 2 budget.

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Reservoir characterization of Antelope Shale and Belridge Diatomite Analysis of Potential for CO2 Flooding of Siliceolls Shales

The project evaluated the economic uncertainties for CO2 flooding of the Belridge Diatomite. Part of the project involved identification and demonstration of several systems to monitor CO2 flood movement within the reservoir and to image the CO2 migration. Implementation of the CO2 flood at Lost Hills field resulted in installation of a four- pattern, 2.5 acre pilot, upgrading facilities, reworking several injection wells and drilling two new injection wells, and construction of CO2 facilities and lines, and setting up a CO2 monitoring system. All construction was completed and CO2 injection began in August 2000. The study evaluated how injection of a very low viscosity gas differed from injection of water into the diatomite in terms of fracture azimuth, injectivity, and areal and vertical sweep.

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Building the Costs Curves for CO2 Storage: North America

IEA GHG has now embarked on a programmed of work to derive the regional costs for CO2 storage. To begin the process of developing the costs for geological storage of CO2, an initial baseline study was completed. The baseline study reviewed the major sources of anthropogenic CO2, and developed a global database of CO2 emission sources detailing quantities and locations. This data base contains details of over 14,000 large emission point sources from the power and industry sectors. Following on from the baseline study two regional studies have now commenced, one in Europe and one in North America. A third study in the series for India was agreed at the 26th ExCo meeting. The regional information developed in these studies, along with data on the costs of capture and transmission, can then be combined to allow future assessments of the comparative costs between CO2 capture and storage and other mitigation options, such as renewable fuels to be undertaken.

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E&P Focus  Vol. 1, No. 1

Department of Energy-funded ?microhole? technology could usher in a revolutionary new approach to the way America's oil and gas wells are drilled. The targeted result: greatly reduced costs and environmental impacts and a wave of new drilling that could help bolster the Nation's energy security. And if progress continues apace for DOE?s microhole research and development program, the technology could be on the cusp of commerciality in just a few years. DOE?s microhole initiative centers on developing technologies related to drilling wells with diameters smaller than 43/4 inches and deploying downhole microinstruments specially designed for such small holes. The idea is to use smaller, transportable drilling rigs to dramatically cut the costs and risks of drilling wells for oil and gas producers while shrinking the ?footprint? of drilling operations and reducing related waste volumes. The microhole technology program is managed by the Office of Petroleum of the Strategic Center for Natural Gas and Oil, an arm of DOE?s National Energy Technology Laboratory. NETL early this year announced the second phase of its microhole initiative. This year's round was designed to push microhole technology another step closer to  commerciality and widespread adoption by the U.S. oil and gas industry. ?This [second round] is the first solicitation round for demonstrations of advanced technology that might become the future of significantly reduced costs for exploration and development,? said Roy Long, Exploration and Production Technology Manager for SCNGO?s Office of Petroleum. ?Within 3 years, we'll know whether we have commerciality for most of these technologies.?

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Basin Oriented Strategies for CO2 Enhanced Oil Recovery: Oklahoma

The oil and gas producing regions of Oklahoma have 45 billion barrels of oil which will be left in the ground, or "stranded oil", following the use of today's oil recovery practices. A major portion of this "stranded oil" is in old reservoirs that appear to be technically and economically amenable to enhanced oil recovery (EOR) using carbon dioxide (CO2) injection. This report evaluates the future oil recovery potential in the large oil fields of Oklahoma and the barriers that stand in the way of realizing this potential. The report then discusses how a concerted set of "basin-oriented strategies" could help the Oklahoma's oil production industry overcome these barriers and capture the large  "stranded oil" prize.

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Risk Reduction with a Fuzzy Expert Exploration Tool

Expert systems are artificial intelligence tools that store and implement expert opinions and methods of analysis. The goal of this project was to test and prove the ability of expert systems to enhance the exploration process and to allow the rapid, simultaneous evaluation of numerous prospects. The project was designed to create two case study fuzzy expert exploration (FEE) tools, one for the Lower Brushy Canyon formation of the New Mexico portion of the Delaware Basin, and the second for the Siluro-Devonian carbonates of southeast New Mexico.

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Reduce Drilling Costs and Environmental Impact Increase Reservoir Imaging Resolution and Real-time Data Acquisition

Reduce Drilling Costs and Environmental Impact Increase Reservoir Imaging Resolution and Real-time Data Acquisition These new technologies will support business models for: - Development of Shallow (5,000 ft) Currently Uneconomic Oil and Gas Resources (Current Solicitation focus). - Lower Drilling Costs result from reduced materials, labor and support equipment. - Lower Environmental Impact results from reduced drilling waste, smaller footprints, and increased transportability for remote, fragile terrains. Pad drilling allows extended wellbore reach without increased environmental risk. -New Economic Seismic Methodologies for Reservoir Imaging (Higher-risk work being conducted by the National Laboratories). - Decrease finding costs by proving exploration targets more economically. - High resolution real-time reservoir information from dedicated boreholes with permanently installed reservoir monitoring systems. Can monitor and optimize IOR  processes for maximum recovery efficiency. - Control over data collection locations  -Designer Seismic? concept allows data to be collected where and when it is needed rather than where production/injection wells have been drilled. - Minimum interruption of production while collecting reservoir data. - Low cost, miniature instrumentation using MEMS (Microelectromechanical) technologies. DOE's Microhole Technology Initiative is developing technologies that enable Coiled Tubing Drilling of 31/2-inch and less boreholes using small, portable coiled tubing drill rigs.

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ASSESSING CONSTRUCTED WETLANDS FOR BENEFICIAL USE OF SALINE-SODIC WATER

Changes in agricultural practices, and irrigation strategies combined with natural processes, have led to increased salinization of soil and water resources worldwide. Coal bed methane (CBM) development in the Powder River Basin of Montana and Wyoming results in the co-production of large volumes of modestly saline-sodic discharge water, and represents a potential source of salinization in areas of CBM development. The objective of this study was to evaluate the potential of constructed wetlands as a tool for CBM product water management. This was accomplished by assessing seasonal water use and water use efficiency (WUE) of three plant communities. Native species establish hydrologically distinct communities in former ephemeral channels now running with CBM product water, and nine species of those cataloged were selected and segregated into three communities. Closed-system wetland cells were constructed and each community was assigned to four of these cells, i.e., lysimeters. Chemistry of the supply water was a relatively low electrical conductivity (EC) and high sodium adsorption ratio (SAR) water (EC~ 3dS/m, SAR >25), typical of northern portions of the Powder River Basin. All three communities had similar seasonal water use but WUE's differed significantly among the communities. This is likely due to overall differences in biomass production, as WUE is a relative value indicating consumptive water use as a function of biomass production. Evaporation from a Class A evaporation pan was observed to be significantly higher than evapotranspiration from the planted lysimeters. This suggests an open water surface has the potential to evaporate more CBM product water than a constructed wetland. Species survivability was very good, with exception of American bulrush (Scirpus americanus) and Inland saltgrass (Distichlis stricta). It was evident American bulrush did not survive the winter while Inland saltgrass was likely out-competed by Creeping spikerush (EZeocharis paZustris). Results indicate that constructed wetlands planted with native, salt tolerant species have the potential to utilize substantial volumes of CBM product water while remaining viable and robust.

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