AndreaBozzo/ceres-open-data-index huggingface dataset:
Chapter 4. REPORT OF THE OHIO DIVISION OF GEOLOGICAL SURVEY TO THE ROME TROUGH CONSORTIUM

The Ohio Division of Geological Survey has been pleased to work with the Kentucky and West Virginia Geological Surveys and sponsors on the Rome Trough Consortium. This joint government-industry consortium was formed to gain a better understanding of the structural and stratigraphic framework of the deep Rome Trough and its production potential. The Kentucky Geological Survey served as the primary contractor to the sponsoring parties and, in turn, subcontracted the geologic interpretations to the respective states. The subcontract to the Ohio Division of Geological Survey required the following tasks: (1) collect subsurface stratigraphic formation tops for 44 selected wells in Ohio and provide data to the Kentucky Geological Survey; (2) provide any existing digital geophysical-log data from these wells in an electronic format to the Kentucky Geological Survey; (3) assist the Kentucky Geological Survey with stratigraphic correlation and cross-section generation.

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Application of High Powered Lasers to Drilling and Completing Deep Wells Status Report

The goal is to develop new, more efficient, cleaner ways to drill and perforate wells through hard rock formations encountered at greater depths. The objective is to extend previous studies of laser drilling, determining: if large holes can be created by lasing small holes adjacent to each other; if lasers can cut rock when submerged in water; how a laser might be employed for perforating; and the effects of wavelength on rock removal.

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Chapter 7. Cambrian and Ordovician Hydrocarbon Geochemistry

The presence of hydrocarbon source rocks in Cambrian sub-Knox Group sedimentary rocks of the Appalachian Basin has been debated for years. Numerous shows of oil and gas in sub-Knox Group rocks have suggested that mature source rocks exist, but the lack of commercial production left doubt as to whether source rocks were rich enough to have formed significant accumulations. Limited production in the 1970?s and 1980?s, and more significant commercial production from the Homer Field in Elliott County, Ky. And a nearby well in Lawrence County, Ky. in the 1990?s indicate that economic Cambrian reservoirs are present in the Appalachian Basin, outside of Ontario, Canada. Data available for the Homer Field from 1997 through 2000 indicate a minimum of 1.8 BCF of gas has been produced (this number does not include data for the first 3 years of production).

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Tight Gas Reservoir Simulation: Modeling Discrete Irregular Strata-Bound Fracture Networks and Network Flow, Including Dynamic Recharge from the Matrix

The U.S. Department of Energy, Federal Energy Technology Center, has sponsored a project to simulate the behavior of tight, fractured, strata-bound gas reservoirs that arise from irregular, discontinuous, or clustered networks of fractures. New FORTRAN codes have been developed to generate fracture networks, to simulate reservoir drainage/recharge, and to plot the fracture networks and reservoir pressures. Ancillary codes assist with raw data analysis. FRACGEN, the fracture network generator, implements four Boolean models of increasing complexity through a Monte Carlo process that samples fitted statistical distributions for various network attributes of each fracture set. Three models account for hierarchical relations among fracture sets, and two generate fracture swarming. Termination/intersection frequencies may be controlled implicitly or explicitly. Using an output file consisting of fracture end-point coordinates and apertures, NFFLOW, the flow simulator, then computes the transient flow rates or bottom-hole pressures according to user-specified pressure or rate schedules, respectively. The flow simulator divides each matrix block into subregions that drain to the midpoint of the adjacent fracture segments in accordance with a one-dimensional, unsteady-flow model. Each idealization approximates both the volume and the mean flow path of each subregion. There is no flow from matrix block to matrix block. Volumetric flow rate in the fractures is modeled as a linear (cubic law) function of the pressure difference between the recharge points and the fracture intersections. The linear function incorporates a "real gas pseudo potential," which allows viscosity and the z-factor to vary with pressure. A requirement of material balance among all intersections couples the individual recharge models together. The resulting equations for material balance at fracture intersections are solved by a Newton-Raphson technique that accommodates a slight nonlinearity caused by matrix recharge. A network consisting of 2300 fractures and 51 time steps was simulated in less than 1 hour (clock time) on a Pentium 200 equivalent computer.

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Gas Exploration, Production, and Storage

Near-Term: Recover more from developed fields - Locate by-passed zones in conventional reservoirs - Enhance stripper well production ? Mid-Term: Exploit low-permeability formations - Reduce drilling cost - Improve success rates in finding gas - Increase recovery efficiency ? Long-Term: Encourage E&P of frontier resources - Deep (>16,000 feet) gas - Methane Hydrates - Offshore gas

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IMPROVED EFFICIENCY OF MISCIBLE CO2 FLOODS AND ENHANCED PROSPECTS FOR CO2 FLOODING HETEROGENEOUS RESERVOIRS

The objective of this work is to improve the effectiveness of CO2 flooding in heterogeneous reservoirs. Our intent is to investigate new concepts that can be applied by field operators within the next two to five years. Activities will consist of experimental research in three closely related areas: 1) further exploration of the applicability of selective mobility reduction (SMR) in the use  of foam flooding, 2) possible higher economic viability of floods at slightly reduced CO:! injection pressures, and 3) taking advantage of gravitational forces during low 1FT, CO:! flooding in tight, vertically fractured reservoirs.

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Comprehensive Environment, Safety and Health Program Implementation Plan for Management and Operating Contract for the Department of Energy's National Oil and Related Programs

BDM-Oklahoma is the Management and Operating (M&O) Contractor for the U.S. Department of Energy's (DOE) National Oil and Related Programs (NORP) which includes the operation of the National Institute for Petroleum and Energy Research (NIPER) in Bartlesville, Oklahoma and other authorized sites. NIPER is a DOE-owned facility where major elements of the NORP are performed. The primary functions conducted at NIPER are advance research and development activities in the area of oil exploration, extraction, and processing and utilization. NIPER is also responsible for transferring newly developed technologies to the domestic oil industry. NIPER currently has no field sites; however, in the future BDM-Oklahoma could develop field sites in the United States to test oil drilling and recovery technologies. Additionally, the DOE Office of Fossil Energy (FE) maintains the Metaire Site Office in New Orleans, Louisiana, to support environmental research programs for the National Oil Program. BDM-Oklahoma will be required to open a branch office to assist the Metaire Site Office. Finally, there are plans for DOE or NIPER to open a liaison office in Russia during 1994 to assist that country in developing its oil reserves. DOE has a group of Federal employees, known as the Bartlesville Project Office (BPO) at the NIPER facility to oversee the M&O contract. BPO personnel assist in interpreting DOE directives, approving budget requests, and monitoring BDM-Oklahoma contractual performance. Under the terms of the M&O contract with DOE, number DE-AC22-94PC91008, BDM Oklahoma is responsible for the daily operation of NIPER and other field sites. BDM Oklahoma conducts all oil research activities, manages technology transfer efforts, and performs all the maintenance and housekeeping operations. One of BDM-Oklahoma's responsibilities is to carry out a fully compliant Environment, Safety and Health program.

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NATURALLY FRACTURED TIGHT GAS RESERVOIR DETECTION OPTIMIZATION

A comprehensive effort is being carried out at LCG to develop, calibrate and test a basin diagenesis simulator for use in the prediction of the distribution and characteristics of tectonic fracture networks and then apply it to the Piceance Basin in coordination with remote sensing and other techniques. Progress on the simulator is approximately on schedule. The simulator has both two- (cross-section) and full three-dimensional options for preliminary and complete modeling,  respectively.  Data from the MWX site is being analyzed and input into a computer data bank. This data will be used to test and calibrate the model. Organic reactions and multi-phase flow were not a part of the original workplan for this modeling facet (subcontract) of the overall project. Nonetheless, its potential importance for the project has led LCG to expend time on developing modules required to account for their effects on overpressure and fracturing. In the course of code development, a technology of computational grid adaption was devised in order to obtain the accuracy in the prediction of fluid pressures and rock stresses needed for fracture prediction. Also, graphical analysis tools needed to visualize our results are being developed based on the AVS (Audio Visual Systems, Inc.) graphics software. In this report preliminary results on all aforementioned aspects of the project are shown. The report ends (Sect. VII) with an estimation of the consistency of progress to date with the originally proposed work schedule and with a bibliography and list of personnel participating in the project.

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Field Fracturing Multi-sites Project

The objective of the Field Fracturing Multi-Sites Project (M-Site) is to conduct experiments to definitively determine hydraulic fracture dimensions using remote well and treatment well diagnostic techniques. In addition, experiments will be conducted to provide data which will resolve significant unknowns with regard to hydraulic fracture modeling, fracture fluid rheology and fracture treatment design. These experiments will be supported by a well-characterized subsurface environment, as well as surface facilities and equipment that are conducive to acquiring high-quality data. The goal is to develop a fully characterized, tight reservoir-typical, field-scale hydraulic-fracturing test site, to diagnose, characterize, and test hydraulic fracturing technology and performance. Improved fracturing technology should increase natural gas recovery and improve development economics.

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Gas Hydrate Distribution in Sands -- Results From Seismic Laboratory Studies

Seismic properties of gas hydrate-bearing sediments largely depend on the microscopic distribution of the gas hydrate crystals in the host sediment. The two end-member models are (1) that gas hydrates are disseminated in the pore space, i.e., crystals are "floating''in the pores and increase the compressional (P-) wave velocity of the pore ``fluid'', and (2) that gas hydrates cement grains and stiffen the sediment matrix. We measured P- wave velocities in gas hydrate-bearing sand samples from the Mallik 2L-38 Research Well, Mackenzie Delta, N.W.T., Canada.

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MEASURING AND PREDICTING RESERVOIR HETEROGENEITY IN COMPLEX DEPOSYSTEMS The Fluvial-Deltaic Big Injun Sandstone in West Virginia

Evidence for heterogeneity in the Big Injun reservoir-forming sandstones on a regional scale is found in the distribution of hydrocarbons into distinct fields across the basin. The easternmost fields traditionally are considered to be updip unconformity traps; those to the west appear to be regionally downdip from the truncated margin of the reservoir.

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RESERVOIR HETEROGENEITY IN CARBONIFEROUS SANDSTONE OF THE BLACK WARRIOR BASIN

Oil production from Carboniferous reservoirs (fig.1) in the Black Warrior basin of Alabama (fig. 2) reached a peak in 1985 (Masingill, 1991) and has declined in recent years although much additional oil may be producible using improved recovery strategies, such as waterflooding, chemical injection, strategic well placement, and infill drilling. High-quality reservoir characterization and reliable criteria for recognition of the types and scale of reservoir heterogeneity are crucial to development of enhanced recovery strategies, because reservoirs typically contain numerous features at megascopic, macroscopic, mesoscopic, and microscopic levels that affect fluid flow (Weber, 1986; Haldorsen and Damsleth, 1993). Previous investigations concerning the Black Warrior basin have been regional in scope, addressing the large-scale depositional setting of reservoir units (for example, Cleaves and Broussard, 1980; Cleaves, 1983; Thomas, 1988). Bearden and Mancini (1985) and Epsman (1987) established salient features pertinent to hydrocarbon production at the field scale, such as trapping mechanism. Because oil production in the basin is declining, secondary recovery projects have been initiated in several oil fields, and improved recovery utilizing advanced technology is being considered, this report, which documents controls on the occurrence and producibility of oil from  heterogeneous Carboniferous reservoirs in the Black Warrior basin, is timely.

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USGS LABORATORY STUDIES SHED LIGHT ON HYDRATE DECOMPOSITION BEHAVIOR UNDER POSSIBLE GAS PRODUCTION SCENARIOS

Producing natural gas from a conventional reservoir requires an understanding of how gas flow changes with reservoir pressure; flow does not depend strongly on reservoir temperature. Producing natural gas by hydrate decomposition depends not only on the in-situ pressures and temperatures, but also on the thermodynamic and other properties of the hydrate system. Methane hydrate decomposition experiments performed at the U.S. Geological Survey show that, because hydrate decomposition requires heat to proceed, reservoir temperatures can drop significantly and ice can form under certain conditions.

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HYDRATE DECOMPOSITION UNDER SCRUTINY

Natural-gas hydrates can form and are stable under specific ranges of elevated gas pressure and temperature, conditions that depend largely on gas composition and hydrate structure. When pressures (P) and temperatures (T) are changed, placing these hydrates outside their stability field, they are prone to decompose at rates that depend on many factors, including hydrate composition and structure, the degree to which the equilibrium boundaries defining the stability field are exceeded, the P-T-time pathway taken to make them unstable, and the physical state and properties of the hydrate and its surroundings.

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Liquid-Free Stimulations - CO2\Sand Dry-Frac

A demonstration project to introduce a unique stimulation process that was previously unavailable to U.S. markets has been initiated. The process utilizes liquid carbon dioxide (CO2) to both create hydraulic fractures and to transport proppants. Carbon dioxide is unique because it vaporizes at reservoir conditions and leaves only a liquid-free proppant pack. The process requires a pressurized closed-system blender to mix the proppant with liquid CO2. The process is non-damaging and can be beneficial to liquid-sensitive reservoirs that are damaged by conventional water-based hydraulic stimulation processes.

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Neutron Powder Diffraction Studies as a Function of Temperature of Structure II Hydrate Formed from a Methane   Ethane Gas Mixture

Neutron powder diffraction data collected at the high resolution powder diffraction beamlines BT-1 (NIST Center for Neutron Research) and HRPD (JRR-3M) confirmed that a hydrate sample with a gas mixture of 82 mol% CH4 and 18 mol % C2H6 crystallizes as structure II hydrate.

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SCANNING ELECTRON MICROSCOPY (SEM) IMAGING OF LABORATORY-GROWN GAS HYDRATES, AND COMPARISONS WITH RECOVERED SAMPLES FROM MARINE AND PERMAFROST ORIGIN

Scanning Electron Microscopy (SEM) serves as a powerful technique for observing grain and pore structure development associated with gas hydrate formation. Here, we use this technique to observe laboratory-synthesized gas hydrates of known purity, composition and pressure-temperature processing histories that formed originally from reaction of a hydrate-forming gas or liquid with melting ice. We present images conveying the range and variety of textures observed at various extents of reaction. We then image synthetic gas hydrate samples used in increasingly complex laboratory and ocean-floor experiments, and compare the observed features to those developed within natural gas hydrate nodules or hydrate zones recovered from both marine and permafrost settings. While accurately identifying in situ growth features and distinguishing them from features produced as artifacts of recovery or handling methods will likely remain problematic in at least the near future, we demonstrate that lab-synthesized samples can be produced to yield remarkably similar textures, phase distribution , and grain contacts as found in at least some hydrate-bearing materials recovered from natural settings.

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Scanning Electron Microscopy investigations of laboratory-grown gas clathrate hydrates formed from melting ice, and comparison to natural hydrates

Scanning electron microscopy (SEM) was used to investigate grain texture and pore structure development within various compositions of pure sI and sII gas hydrates synthesized in the laboratory, as well as in natural samples retrieved from marine (Gulf of Mexico) and permafrost (NW Canada) settings. Several samples of methane hydrate were also quenched after various extents of partial reaction for assessment of mid-synthesis textural progression. All laboratory-synthesized hydrates were grown under relatively high-temperature and high-pressure conditions from rounded ice grains with geometrically simple pore shapes, yet all resulting samples displayed extensive recrystallization with complex pore geometry. Growth fronts of mesoporous methane hydrate advancing into dense ice reactant were prevalent in those samples quenched after limited reaction below and at the ice point. As temperatures transgress the ice point, grain surfaces continue to develop a discrete ?rind? of hydrate, typically 5 to 30 ?m thick. The cores then commonly melt, with rind micro fracturing allowing migration of the melt to adjacent grain boundaries where it also forms hydrate. As the reaction continues under progressively warmer conditions, the hydrate product anneals to form dense and relatively pore-free regions of hydrate grains, in which grain size is typically several tens of micrometers. The prevalence of hollow, spheroidal shells of hydrate, coupled with extensive redistribution of reactant and product phases throughout reaction, implies that a diffusion-controlled shrinking-core model is an inappropriate description of sustained hydrate growth from melting ice. Completion of reaction at peak synthesis conditions then produces exceptional faceting and euhedral crystal growth along exposed pore walls. Further recrystallization or regrowth can then accompany even short-term exposure of synthetic hydrates to natural ocean-floor conditions, such that the final textures may closely mimic those observed in natural samples of marine origin. Of particular note, both the mesoporous and highly faceted textures seen at different stages during synthetic hydrate growth were notably absent from all examined hydrates recovered from a natural marine-environment setting.

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Argonne's Modeling Capabilities for Developing Candidate Deep Well Cements - A Case Study of Aluminum Phosphate Cement

ANL has developed capabilities to develop novel phosphate cements for deep well applications. ANL approach consists of, 1) using thermodynamics and predicting solubility of range of oxides and minerals and then determining whether a particular material is suitable for formation of cements, 2) using differential thermal and X-ray diffraction analyses to test the suitability, 3) to produce cement at an elevated temperature in air and confirming results of the previous two steps, and then 4) testing the cement in oil well conditions and modifying the process to comply with American Petroleum Institute’s guidelines for pumping cements. In this report, the approach is summarized and with the example of alumina, it is shown that this material may be one most suitable for development of the deep well cement. We recommend that this material be considered for development as phosphate cement for deep wells.

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Hydraulic Motion & Fluid Movement Through Small Diameter Pipes and Wellbores

The purpose of this document is to identify information regarding hydraulic motion and fluid dynamics through small diameter pipes and well-bores. Of particular interest will be tubing diameters ranging from 3.00? to approximately 1.00? with specific application for Coil Tubing Drilling (CTD). As a result of this requirement, an extensive literature search was conducted that included, but not limited to, academic research, professional and technical papers, patents, professional periodicals, government research projects and technical manuals from coil tubing manufacturers. The scope of this document will include any available information specific to technologies associated with the dynamics of fluid motion during drilling and production operations. As a result of this statement, the formation and conclusion of this document will specifically pertain to critical factors regarding the drilling process and the subsequent production rates from various coiled tubing diameters if available. The data will include critical factors of fluid behavior, any available simulations and a general understanding of fluid flow in the process of CTD.

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ADVANCED SENSOR TECHNOLOGY FOR MICROBOREHOLE AND OTHER SEISMIC APPLICATIONS

The cost and operational limitations of deploying downhole seismic sensors have often precluded the acquisition of important reservoir data. The need exists for a retrievable borehole seismic package or array that can be repeatedly deployed in production wells without pulling production tubing for each use. Engineering calculations, cost analyses and scientific discussion have shown the technical feasibility of using coiled tubing and miniaturized hardware for drilling 1.125 in. diameter boreholes to depths ranging form 100 to 10,000 ft. Modern electronics and advances in sensor technology make the  miniaturization of borehole packages possible. Microboreholes have the potential to be drilled for less than one-fifth the cost of conventional wellbores. The goal was to develop, evaluate and field test miniature sensors for use in microboreholes.

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