AndreaBozzo/ceres-open-data-index huggingface dataset:
Data Collection Protocol for Developing Geographical Information Systems to Investigate and Manage Ecological Impacts at Petroleum Exploration and Production Sites

To support the development of an ecological framework for E&P sites, a web-based GIS that will serve to organize and integrate numerous data sets from E&P sites is desirable. In this document we describe our work to date in developing protocols to: 1) acquire data, 2) assess its scope, quality, accuracy, precision, and applicability, 3) establish spatial data in a common projection system, 4) associate tabular data with spatial locations where useful, 5) preprocess or correct data as needed, and 6) maintain the data for the research consortium for use in models, analyses, presentations, and publications, as needed. This document will be revised as protocols are developed in greater detail.

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Land and Water Inventory Guide for Landowners in Areas of Coal Bed Methane Development

This guidebook was developed and is being made available by the Regional 8 Coordinated Regional Natural Resource Monitoring and Training Program team, a USDA-CSREES funded coordination team. As U.S. domestic demand for natural gas grows, so has the coal bed methane industry.  In an effort to enhance communication among water quality specialists in Montana, Wyoming, Colorado, and Utah and with our EPA Region 8 partners, we have co-developed this guide to address significant resource management issues encountered within the region.

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ENERGY EFFICIENCY AND FOSSIL ENERGY RESEARCH 1978 TO 2000

Conventional methods of oil recovery, including primary and secondary recovery, achieve, on the average, about 35 percent recovery of the original oil in place, less if the oil is heavy or viscous. The volume of oil remaining in already-discovered reservoirs in the United States is on the order of 340 billion barrels. Conventional wisdom in the 1970s held that additional recovery would involve a physical or chemical change in the reservoir or its contained fluids to move oil that was immobile.

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Seismic Studies of the Gas-Hydrate-Stability Zone, Northern Gulf of Mexico

High-resolution seismic-reflection data were collected across the upper- and middle-continental slope of the northern Gulf of Mexico to study the distribution of gas and gas hydrate and their relation to seafloor slides. Seafloor gas vents and gas hydrate are widely reported near salt-related structures, but gas hydrate is only reported in one deep drill site. In our study area, the upper 1000 m subbottom, which includes the gas-hydrate-stability zone (GHSZ), has many high-reflectivity zones (HRZs) that lie at varied subbottom depths near shallow diapirs, faults and likely debris flows, and that are interbedded within layered sedimentary sections. HRZs occur near seafloor gas vents and along faults, lie below (more common) and within the GHSZ, and coincide with zones of shallow water-flows. Bottom simulating reflections are rare in the Gulf, and not seen in our data. We believe HRZs result largely from free gas in sandy beds. These beds would also contain hydrates within the GHSZ. We estimate base GHSZ for methane and two petrogenic gases, and on seismic sections the base GHSZ correlates reasonably with top of HRZs in some thick well-layered basin sections, but poorly where shallow sediments are thin and strongly deformed. The correlation is equivocal in part because the values used to calculate estimates of base GHSZ are poorly constrained and may vary widely, especially near areas of large water- and sediment-flows. HRZs may be a potential indicator for nearby gas hydrate. HRZs also lie at the base of at least two large seafloor slides (e.g., up to 250 sq. km.) that may be actively moving along decollement faults that sole within the GHSZ or close to the estimated base of the GHSZ. We suspect that water/gas flow along these faults and adjacent strata provide gas to source gas hydrate in the GHSZ, and flow weakens sediments that slide on salt oversteepened slopes when triggered by earthquakes.

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Laboratory Measurement of Compressional and Shear Wave Speed in Polycrystalline sI and sII Gas Hydrates and Ice as Functions of Temperature and Pressure

We report on laboratory measurements of compressional and shear wave speeds in compacted, polycrystalline sI methane and sII methane-ethane hydrates and ice Ih. The hydrate samples were made from granulated ice warmed to 290 K in the presence of methane or methane-ethane gas at high pressure. The resulting porous gas hydrate samples were uniaxially compacted within the synthesis pressure vessel using a hydraulic ram with a moving piston and fixed end plug fitted with shear transducers. Once the samples were fully compacted, the temperature was cycled in steps from 258 to 288 K while the uniaxial pressure was held constant at 60 MPa. After temperature cycling was completed, the uniaxial pressure was varied between 30 and 90 MPa at 283, 273, 263 and 253 K. At the end of each experiment, the uniaxial pressure was slowly decreased to 1 atm at 253 K. Shear and compressional wave speed measurements were made throughout each experiment. For ice Ih, the sample was evacuated before compaction, the measurement temperature range was 253 to 268 K and the applied uniaxial pressure did not exceed 42 MPa. Analysis of the data produces several interesting observations. Among them are: 1) sI and sII gas hydrate resist compaction much more than ice. A pressure of 42 MPa fully compacted the ice sample at 268 K, but a pressure of 105 MPa had to be applied for several days (at temperatures of 253, 278 and 288 K) to fully compact the hydrate samples. 2) Wave speed increases at constant sample length strongly suggest grain to grain bonds form between adjacent ice or gas hydrate grains. The relative wave speed increases with time show this process is more efficient in ice samples, perhaps due to the higher mobility of water in ice's crystal lattice. 3) Within the pressure and temperature conditions studied, the wave speed based calculations of Poisson's ratio are 5 to 6\% smaller in sI and sII gas hydrate than in ice. 4) Shear wave speed decreases with increasing uniaxial pressure in Ice Ih, sI methane and sII methane-ethane hydrate. This unusual behavior was well known in ice Ih but was not known to apply to gas hydrates because no independent measurements of shear wave speed versus pressure in gas hydrates were previously available.

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Using surface geochemistry to locate bypassed oil

Surface geochemistry can be combined with subsurface data to help delineate pockets of bypassed oil and refine subsurface structure in mature fields. In the case presented here, soil samples were collected on a series of grids spread over 6 months culminating in a 50-meter grid and processed for presence of soil-gas hydrocarbons. Contour maps of hydrocarbon soil concentration show good correlation between the revised subsurface structure based on drilling with the distribution of geochemical highs. Although a developing technology, surface geochemistry shows promise in economically lowering drilling risk in redevelopment projects.

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Technology Introduction

The Oil Program began to focus on seismic technology in the late 1980s. The Oil Program had conducted a major demonstration program beginning in the mid-1970's to develop and demonstrate enhanced oil recovery to recover more of the oil left after conventional and waterflood recovery. Twenty-seven projects in this demonstration program were high-risk but that had an excellent benefit potential if the process was successful. Post mortems of many of the unsuccessful projects highlighted the primary reason for failure was a lack of reservoir characterization. The DOEIFE then began the process to identify those reservoir characterization technologies that were needed to reduce risk and enhance success of enhanced oil recovery technologies.

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

Currently work is being performed on Tasks 1.1, 1.2, 1.3, 1.4, 2.0, 7.0 and 8.0. Well data and lease production history data have been largely collected, inventoried and scanned for web access. A preliminary quantitative reservoir model was constructed in the previous quarter. Phase I numerical reservoir simulation (Task 1.4), preliminary remediation and testing of the Colliver #18 (Task 2.1.7), and drilling of the new CO2 injector, Carter Colliver #1 CO2 I (Task 2.1) were major activities performed. During simulation the quantitative reservoir model was modified and reexamined (Tasks 1.2-1.3). In addition, the website was expanded to included a clickable map with links to logs, well completion diagrams, and other well data (Task 1.1).

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Task 6.5/6.7.1 - Materials for Gas Separation and Hydrogen Separation Membranes

Catalytic gasification of coal to produce H2- and CH4-rich gases for consumption in molten carbonate fuel cells is currently under development; however, to optimize the fuel cell performance and extend its operating life, it is desired to separate as much of the inerts  as possible from the fuel gas before they enter the fuel cell. In addition, the economics of the integrated gasification combined cycle (IGCC) can be improved by separating as much of the hydrogen as possible from the fuel, since hydrogen is a high-value product. One process currently under development by the Energy & Environmental Research Center (EERC) for accomplishing this gas separation and hot-gas cleanup involves gas separation membranes. These membranes are operated at temperatures as high as 8000 C and pressures up to 300 psig. Some of these membranes can have very small pores (30-50 ~), which inefficiently separate the undesired gases by operating in the Knudsen diffusion region of mass transport. Other membranes with smaller pore sizes ( <5 ~) operate in the molecular sieving region of mass transport phenomena. Dissolution of atomic hydrogen into thin metallic membranes made of platinum and palladium alloys is also being developed.    Technological and economic issues that must be resolved before gas separation membranes are commercially viable include improved gas separation efficiency, membrane optimization, sealing of membranes in pressure vessels, high burst strength of the ceramic material, pore thermal stability, and material chemical stability. Hydrogen separation is dependent on the temperature, pressure, pressure ratio across the membrane, and ratio of permeate flow to total flow.

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Cyclic CO2 stimulation to Improve CO2 Flooding - Oxy's Field Project

In this project, Oxy USA, Inc., is demonstrating the advantages of applying advanced reservoir management techniques, hydraulic fracturing and cyclic CO2 stimulation to improve the economics and efficiencies of CO2 floods in previously waterflooded carbonate reservoirs in the Permian Basin of West Texas. Working in the South Welch Unit, Oxy used advanced three-dimensional seismic imaging and log and core analysis to obtain a thorough description of the San Andres Formation reservoir to assist in the design of the most effective recovery processes Fractures were created by injecting pressurized fluids into the reservoir strata to provide gas injection efficiency. The length and orientation of the fractures were determined to design the most efficient reservoir fluid flow patterns.

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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; (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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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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Investigation and Demonstration of Dry Carbon-Based Sorbent Injection for Mercury Control

The U.S. Department of Energy (DOE) issued Public Service Company of Colorado (PSCO) a cost sharing contract to evaluate carbon-based sorbents for mercury control on a 600 acfm laboratory-scale particulate control module (PCM). The PCM can be configured as simulate an electrostatic precipitator, a pulse-jet fabric filter, or a reverse-gas fabric filter and is installed on an operating coal-fired power plant. Three different dry carbon-based sorbents were tested this quarter to determine their mercury removal capability in the different configurations.  The project is currently in the seventh quarter of an eight-quarter Phase I project. Testing  in all configurations is nearly complete. Original plans included the use of an on-line mercury analyzer to collect test data. However, due to very low baseline mercury concentration, on-line measurement did not provide accurate data. The project used a modified MESA method grab sample technique to determine inlet and outlet mercury concentrations. A major concern during sorbent evaluations was the natural ability of the flyash at the test site to remove mercury. This often made determination of sorbent only mercury removal difficult.     The PCM was configured as a reverse-gas baghouse and brought online with "clean" flue gas on March 10* at an A/C of 2.0 ft/min. The dustcake forms the filtering media in a reverse gas baghouse. In the absence of flyash, the bags were precoated with a commercially available alumina silicate material to form an inert dustcake. Some baseline tests were completed with clean gas for comparison to clean gas pulse jet tests.  The PCM was reconfigured as a TOXECON unit in April 1997 with testing completed in May 1997. TOXECON, an EPIU patented technology, is a pulse-jet baghouse operating at a high A/C ratio downstream of a primary particulate colIector with sorbent injection upstream of the baghouse for air toxics removal. Mercury removals of O to 97o/0 were obtained depending on test conditions.

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Optimization of Coal Particle Flow Patterns in Low N0x Burners

The proposed research is directed at evaluating the effect of flame aerodynamics on NOX emissions tlom coal fired burners in a systematic manner. This fimdamental research includes both experimental and modeling efforts being petiormed at the University of Arizona in collaboration with Purdue University. The objective of this effort is to develop rational design tools for optimizing low NOX burners to the kinetic emissions limit (below 0.2 lb./MMBTU). Experimental studies include both cold and hot flow evaluations of the following parameters: flame holder geometry, secondary air swirl, primary and secondary inlet air velocity, coal concentration in the primary air and coal particle size distribution. Hot flow experiments will also evaluate the effect of wall temperature on burner performance. Cold flow studies will be conducted with surrogate particles as well as pulverized coal. The cold flow furnace will be similar in size and geometry to the hot-flow furnace but will be designed to use a laser Doppler velocimeter/phase Doppler particle size analyzer. The results of these studies will be used to predict particle trajectories in the hot-flow fhrnace as well as to estimate the effect of flame holder geometry on furnace flow field. The hot-flow experiments will be conducted in a novel near-flame down-flow pulverized coal furnace. The fhrnace will be equipped with externally heated walls. Both reactors will be sized to minimize wall effects on particle flow fields. The cold-flow results will be compared with Fluent computation fluid dynamics model predictions and correlated with the hot-flow results with the overall goal of providing insight for novel low NOX burner geometry's.

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Proceedings of the Gulf of Mexico Hydrates R&D Planning Workshop

The National Energy Technology Laboratory (NETL) and the Chevron Petroleum Technology Company hosted the Gulf of Mexico (GOM) Hydrates R&D Planning Workshop on August 9-10, 2000. The purpose was to gather stakeholder input on the opportunities and challenges for hydrate research and development (R&D) needs in the areas of drilling safely, seafloor stability, resource characterization, and production technology for the GOM. These workshop proceedings include all of the speaker presentations, question and answer documentation, and three appendices for the breakout session products, the participant list, and the poster session. The proceedings are publicly available at the NETL website: www.netl.doe.gov, where CD-ROM ordering is also available. During the workshop, participants actively shared ideas through facilitated sessions. Structured brainstorming and critical analysis were used to identify barriers and technology opportunities and to build consensus on collaborative actions. The workshop is expected to enhance dialog with industry on how to develop strategic alliances among industry, academia, and government.

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Geomechanics for Reservoir Management

Oil and gas reservoirs are dynamic systems that are constantly changing during their production history. As production draws down reservoir pressure, changes take place in the reservoir in the form of effective stresses, reduced permeability and fracture flow characteristics in stress sensitive reservoirs such as the fractured chalk reservoirs in Texas and the overpressured reservoirs in the Gulf of Mexico. Quite often, severe subsidence accompanies pressure draw down in reservoirs such as the high-porosity diatomite fields in California or the Chalk reservoirs in the North Sea, causing severe casing damage, borehole breakouts and other problems. For example, during 1935-65 the surface above the Wilmington oil field in California subsided 33?, costing damage in excess of $100 MM to various facilities. By 1987 about 13? of seafloor subsidence was measured above the Ekofisk field in North Sea and the entire cost to raise platform and to protect storage facilities exceeded $400 MM. Casing failures have occurred in more than two-thirds of the wells in this field. Sandia National Laboratory has adopted an integrated geomechanics approach based on laboratory, field research and numerical model simulations to understand and develop tools for managing the stress-sensitive reservoirs. Detailed field and laboratory studies of deformation features such as fractures, bands etc. have been completed on a number of stress-sensitive formations to understand the genesis of these features for planning the most effective recovery operations. Because of the apparent relationship between compaction bands and certain borehole breakouts, Sandia organized a special session during the fall meeting of the American Geophysical Union in 1999 to discuss this important production problem. Using idealized network models, the complexity of hydraulic flow paths in heterogenous porous media has been demonstrated. This will help to understand the mechanism of displacement of oil from pore space during waterflooding or enhanced oil recovery processes and in predicting transportation of contaminants in an underground aquifer. Improved simulation of fractured reservoirs will lower development costs of these reservoirs by 10%. The 3-D, nonlinear finite-element geomechanical simulation of the Lost Hills and the Belridge fields in California reveal the evolution of the subsurface stress and the displacement fields in the reservoirs and the overburden, and show how production and injection patterns affect their spatial and temporal variations. This simulation is being applied as a reservoir management tool to mitigate surface subsidence and well failures. It is estimated that this technology will reduce well failure from 10% to 5%, thereby saving the operators $25-$50 MM per year. Successful implementation of tools for managing stress-sensitive reservoirs developed in this project should help to add 5.2 BBO and 58.0 TCF of natural gas to the national reserves that will ultimately generate $34 and $12 billion in royalties and taxes and 60,000 new jobs in different sectors.

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High Temperature High Pressure Thermodynamic Measurements for Coal Model Compounds

The overall objective of this project is to develop a better thermodynamic model for predicting properties of high-boiling coal derived liquids, especially the phase equilibria of different fractions at elevated temperatures and pressures. The development of such a model requires data on vapor-liquid equilibria (VLE), enthalpy, and heat capacity which would be experimentally determined for binary systems of coal model compounds and compiled into a database. The data will be used to refine existing models such as UNIQUAC and UNIFAC.  The flow VLE apparatus designed and built for a previous project was upgraded and recalibrated for data measurements for thk project. The modifications include better and more accurate sampling technique and addition of a digital recorder to monitor temperature, pressure and liquid level inside the VLE cell. VLE data measurements for system benzene-ethylbenzene have been completed. The vapor and liquid samples were analysed using the Perkin-Elmer Autosystem gas chromatography.

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