AndreaBozzo/ceres-open-data-index huggingface dataset:
VERY HIGH-SPEED DRILL STRING COMMUNICATIONS NETWORK

A history and project summary of the development of a very high-speed drill string communications network are given. The summary includes laboratory and field test results, including recent successes of the system in wells in Oklahoma. A brief explanation of commercialization plans is included. The primary conclusion for this work is that a high data rate communications system can be made sufficiently robust, reliable, and transparent to the end user to be successfully deployed in a down-hole drilling environment. A secondary conclusion is that a networking system with user data bandwidth of at least 1 million bits per second can be built to service any practical depth of well using multiple repeaters (Links), with spacing between the Links of at least 1000 ft.

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Advanced High-Pressure Coiled-Tubing Drilling System

The majority of time and cost in drilling a gas or oil well is consumed by the actual drilling process (?turning to the right?). The most effective approach to significantly reduce costs of drilling wells is to increase penetration rates. Researchers have for many years investigated means to drill rock faster, and jet-assisted drilling is one method that has been considered several times. In most cases it was found that, while jet-assisted drilling was very effective in increasing penetration rates, the implementation cost was too high because special equipment and pumps were required. Research has shown that most formations can be drilled significantly faster and that well depth is not a significant factor in the results.

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Coiled Tubing: State of the Industry and Role for NETL

The use of coiled tubing (CT) to conduct well intervention services is well established. With improving technology, the use of CT has continued to grow at an average rate of ten percent per year, even as other services decline. The National Energy Technology Laboratory (NETL) has historically and currently sponsors and directs a number of CT related research projects as part of the U.S. Department of Energy (DOE) goal to develop technologies to recover a higher percentage of domestic oil deposits and slow the decline of U.S. oil production. A recent study was conducted to help formulate a road map for future co-funded research in coiled tubing, coiled tubing drilling (CTD), slimhole/microhole and related technologies. The thrust of the first phase was to look at this relatively new (CTD) industry: identify the level of activity, the dominant service providers, applications and geographical distribution of activity. Second, to examine, in some detail the use of coiled tubing for grass roots drilling ? the advantages, disadvantages, limitations, costs and why it has flourished in Alberta Province and not elsewhere, particularly the lower 48 states. Finally, the results of a technology assessment was reported: identifying the cutting edge applications that are out in the field and what research is underway with Joint Industry Partners, universities and technology companies, some DOE co-funded, much of it not. Information was gathered through available public sources and through private discussions with a spectrum of industry experts. The second phase of the study focused on DOE funded research for coiled tubing generally, and coiled tubing drilling in particular. The related interest areas of slimhole/microhole drilling, high speed drilling and monitoring gas-flooded oil reservoirs with vertical seismic profiling were also examined. The research in these areas co-funded by DOE in the mid-1990s was general in nature. This is in contrast with the focused research in the above topics begun in the last two years. An assessment of industry acceptance and potential market was made for coiled tubing well intervention; coiled tubing conveyed drilling of slimholes/microholes for shallow production, exploration logging, lateral extension, and reservoir monitoring. In this phase as well, information was gathered from both public sources and private discussions with the principal investigators of DOE co-funded projects and other industry experts.

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IMPROVING CO2 EFFICIENCY FOR RECOVERING OIL IN HETEROGENEOUS RESERVOIRS

This document is the Final Report for the U.S. Department of Energy under contract No. DEFG26- 01BC15364, a three-year contract with a no-cost extension entitled: ?Improving CO2 Efficiency for Recovering Oil in Heterogeneous Reservoirs.? This research improved our knowledge and understanding of CO2 flooding and included work in the areas of injectivity and mobility control. Chapter 1 summarizes a survey performed for all the CO2 injection projects in the Permian Basin. Chapter 2 covers CO2-brine-reservoir rock interactions that were studied to better understand injectivity implications. Chapter 3 summarizes work performed to determine possible injectivity and productivity reduction due to high flow rate in near-wellbore regions, and Chapter 4 summarizes work in the areas of foam stability, interfacial tension, surfactant adsorption and desorption, and mobility control. Chapter 5 lists the papers, reports, workshops, and presentations produced as a result of the research work under this contract. The work performed under this contract and the results achieved through this research in the related fields of mobility control and injectivity will improve industry understanding of CO2 flooding mechanisms, with the ultimate goal of economically recovering more of the U.S. oil reserves. Results include: ? Identification of the extent that various properties affect foaming agent adsorption, i.e.: rock type, surfactant type, surfactant concentration, co-surfactants, sacrificial agents, brine salinity, pH, and temperature. ? Understanding of the extent of synergistic effects on adsorption and desorption in dual chemical systems for five powdered minerals and three rock types. ? Identification of parameters that change injectivity and improve sweep efficiency. ? Identification of causes of injectivity changes: fines migration, permeability changes, dissolution, precipitation, stress/pressure gradient, phase behavior, flow rate, etc. ? Development of models to predict advancing rates of individual components in mixed chemical systems with adsorption and desorption kinetic and equilibrium rates, foam behavior in heterogeneous systems, and injectivity.

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“Basin Analysis and Petroleum System Characterization and Modeling, Interior Salt Basins, Central and Eastern Gulf of Mexico”

The principal research effort for Year 2 of the project has been data compilation and the determination of the burial and thermal maturation histories of the North Louisiana Salt Basin and basin modeling and petroleum system identification. In the first nine (9) months of Year 2, the research focus was on the determination of the burial and thermal maturation histories, and during the remainder of the year the emphasis has basin modeling and petroleum system identification. Existing information on the North Louisiana Salt Basin has been evaluated, an electronic database has been developed, regional cross sections have been prepared, structure and isopach maps have been constructed, and burial history, thermal maturation history and hydrocarbon expulsion profiles have been prepared. Seismic data, cross sections, subsurface maps and related profiles have been used in evaluating the tectonic, depositional, burial and thermal maturation histories of the basin. Oil and gas reservoirs have been found to be associated with salt-supported anticlinal and domal features (salt pillows, turtle structures and piercement domes,1631 ); with normal faulting associated with the northern basin margin and listric down-to-the basin faults (state-line fault complex) and faulted salt features; and with combination structural and stratigraphic features (Sabine and Monroe Uplifts) and monoclinal features with lithologic variations. Petroleum reservoirs are mainly Upper Jurassic and Lower Cretaceous fluvial-deltaic sandstone facies and Lower Cretaceous and Upper Cretaceous shoreline, marine bar and shallow shelf sandstone facies. Cretaceous unconformities significantly contribute to the hydrocarbon trapping mechanism capacity in the North Louisiana Salt Basin. The chief petroleum source rock in this basin is Upper Jurassic Smackover lime mudstone beds. The generation of hydrocarbons from Smackover lime mudstone was initiated during the Early Cretaceous and continued into the Tertiary. Hydrocarbon expulsion commenced during the Early Cretaceous and continued into the Tertiary with peak expulsion occurring mainly during the Late Cretaceous.

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TOC and Rock-Eval or SR Analyzer Interpretive Guidelines

Total organic carbon (TOC) and Rock-Eval or SR Analyzer analyses are the two most common analyses initiated on rock samples to assess various bulk geochemical characteristics. These techniques were first used to assess the source potential and thermal maturity of cuttings, core, or outcrop samples as an initial screening step. It is now common to evaluate potential reservoir rocks to assess the oil content and oil quality by prediction of API gravity.

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The SAFOD Project

Basic Survey information -Client: EarthScope, Client Reps: Mark Zoback, Steve Hickman and Bill Ellsworth, -Area: Parkfield, California -Survey dates: April 30th to May 10th 2005 -Seismic datum: 670 m above msl. GL at the SAFOD well is 660.5m above msl. - Well name: SAFOD Well - Surface seismic source for zero offset: 5 lb of dynamite at 10 ft depth -Surface seismic source for offset shots: 80 lb of Pentolite (charge is 60 ft long) at 100 ft depth - Number of shot points recorded: 5 zero offset shots, 13 offset shots -Horizontal offsets recorded: 150 ? 15,000 ft (50 m ? 5,000 m) -Well information: Casing size: 9 5/8?, Casing weight: 47 lb/ft, drifted diameter 8.525?  -Receiver array: P/GSI Cable 80-010, pod spacing: 15.2 m (50 ft), Phones: 15 Hz OYO  Geospace SMC15-1850 Omni, 3C pod

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THERMAL PROPERTY MEASUREMENTS IN TETRAHYDROFURAN (THF) HYDRATE AND HYDRATE-BEARING SEDIMENT BETWEEN -25 AND  4  C, AND THEIR APPLICATION TO METHANE HYDRATE

We present simultaneous measurements of thermal conductivity, thermal diffusivity and specific heat in ice Ih, Tetrahydrofuran (THF) hydrate and THF hydrate   crystalline quartz.

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Water Quality of the Quaternary and Ada-Vamoosa Aquifers on the Osage Reservation, Osage County, Oklahoma, 1997

The project was to provide information on the quality of ground water from rural-domestic-water wells within the Osage Reservation and compare the water-quality to proximity to oil wells. About 38,500 oil wells have been drilled in the Reservation since drilling began in 1896. About 1,480 square miles or 64 percent of the Reservation is within a quarter mile of an oil well. The unconfined Quaternary sand aquifer covers about 315 square miles or about 14 percent of the Reservation and the confined Ada-Vamoosa sandstone aquifer covers about 800 square miles or about 35 percent of the Reservation. Fifty-eight percent of the Quaternary aquifer and 69 percent of the outcrop area of the Ada-Vamoosa aquifer are within a quarter mile of an oil well. One hundred twenty domestic ground-water wells were sampled from the Quaternary and Ada-Vamoosa aquifers. Forty-nine percent of the Reservation is underlain by the aquifers. Ground-water quality is good on most of the Reservation, but the use of domestic- water-supply wells tend to minimize water-quality problems. Existing water-supply wells commonly are located in areas that produce usable volumes of potable water. Several constituents in samples from the Ada-Vamoosa-aquifer within a quarter mile of an oil well were significantly greater than from the aquifer not near oil wells. The constituents include specific conductance, dissolved solids, sodium, sulfate, chloride, bromide, and silica. These ions are probably derived from brine water. In the Ada-Vamoosa aquifer subgroups, 57 percent of the samples near oil wells and 24 percent of the samples not near oil wells had dissolved- solids concentrations greater than 500 milligrams per liter. The water quality in the Quaternary and Ada-Vamoosa aquifers is similar in areas where no oil wells have been drilled but is significantly different for several constituents. Median concentrations of major constituents from the Ada-Vamoosa aquifer not near oil wells were less than or equal to values from the Quaternary aquifer. Sixty-four percent of the water-quality samples from the Quaternary and 51 percent from the Ada-Vamoosa aquifers have dissolved- solids concentrations less than the secondary drinking water regulations of 500 milligrams per liter. Fifty-nine percent of the aquifer samples in the Quaternary aquifer subgroups not near oil wells and 70 percent of the samples near oil wells had dissolved solids less than 500 milligrams per liter. Areas in the Ada-Vamoosa aquifer near Hominy, Pershing, and Hula Lake have dissolved-solids concentrations greater than the secondary drinking water regulations. Water-quality samples from the Quaternary aquifer in these areas also have dissolved-solids concentrations greater than 500 milligrams per liter.

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Overview of Williston Basin Geology as it Relates to CO2 Sequestration

The geology of carbon dioxide (CO2) sequestration is essentially the geology of petroleum exploration. Basically, the search for oil is the search for sequestered hydrocarbons. Therefore, the geological conditions that are conducive to hydrocarbon sequestration are also the conditions that are conducive to CO2 sequestration. The three requirements for sequestering hydrocarbons are a hydrocarbon source, a suitable reservoir, and an impermeable trap. These requirements are the same as for sequestering CO2, except that the source is artificial and we refer to the reservoir as a sink. Reviewing the tectonic origin and structure of a basin, as well as its hydrogeology and geology, including the petroleum geology, can lend valuable insights in any attempt to identify geological sinks for CO2 sequestration in an oil-producing basin.

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Model Calibration and Efficient Reservoir Imaging(MCERI)

Streamline models are routinely used for waterflood optimization and management, and are being extended to more complex processes, e.g., compositional simulation. Despite these new developments, no systematic study has examined the underlying numerical spatial and temporal discretization errors in streamline simulation and their convergence. Such studies are a prerequisite to determining the optimal density of streamlines during simulation and ensuring the resulting accuracy of the solution. In this paper we first examine transverse spatial errors, e.g., errors due to the number or placement of streamlines. We provide an analytic proof and a numeric demonstration of the order of spatial convergence of the mass balance discretization error. Both global and local calculations are performed, and demonstrate the impact of stagnation regions on the order of convergence. A second transverse error arises for faulted grids, where lack of flux continuity at cell faces can lead to incorrect trajectories. These trajectory errors are of zeroth order, and can only be resolved by introducing additional degrees of freedom into the streamline velocity model. Longitudinal spatial errors also arise, and are associated with the inaccurate calculation of time of flight across cells. We show that the commonly used algorithm for corner point cells leads to inaccurate time of flight calculations for stratigraphic grids, depending upon aspect ratio. We provide a simple and exact means of calculating the time of flight for arbitrary corner point cells, or unstructured grids, in two or three dimensions, for either compressible or incompressible flow. Finally, using this new time of flight formulation, we analyze a series of cross-sectional finite difference simulations to identify grid orientation errors in the numerical calculation of flux and spatial error.

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Heterogeneous Shallow-Shelf Carbonate Buildups in the Blanding Sub-Basin of the Paradox Basin, Utah and Colorado: Targets for Increased Oil Production and Reserves Using Horizontal Drilling Techniques

Increase production and reserves from the shallow shelf carbonate reservoirs in the Ismay and Desert Creek zones of the Pennsylvania age Paradox Formation, in the Paradox Basin of Utah and Colorado. The project proposed using horizontal laterals from existing vertical field development wells to optimize production.

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Assessing Subeconomic Natural Gas Resources in the Anadarko Basin

Natural gas resource assessments are a commonly used tool by industry, academia, and government to understand the current and near-term recoverability of the nation's resource base. However, these resource assessments tend to be static pictures of a resource that is, in reality, highly dynamic. Assessments based on gas-in-place (GIP) analysis and iterative modeling of resource recoverability under a variety of technology/policy scenarios provide improved means to identify the most promising approaches to expanded resource recoverability.

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Assessing Sub-economic Natural Gas Resources in the Anadarko and Uinta Basins

Natural gas resource assessments are a commonly used tool by industry, academia, and government to understand the current and near-term recoverability of the nation's resource base. However, these resource assessments tend to be static pictures of a resource that is, in reality, highly dynamic. Assessment based on gas-in-place (GIP) analysis and iterative modeling of resource recoverability under a variety of technology/policy scenarios provide improved means to identify the most promising approaches to expanded resource recoverability.

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Stratigraphic Framework, Structure, and Thermal Maturity of Cretaceous and Lower Tertiary Rocks in Relation to Hydrocarbon Potential, Crazy Mountains Basin, Montana

The Crazy Mountains Basin in south-central Montana, a sparsely explored deep basin with a complex depositional and structural history, was investigated for basin-centered gas accumulations. The basin formed largely in response to thrust loading along the Helena salient, an eastward bulge in the Sevier orogenic belt just west of the deep basin trough, in Late Cretaceous (Maastrichtian) and Paleocene time. Drilling is too sparse to detect the presence of a basin-centered gas accumulation, so other Rocky Mountain basins serve as analogs as many contain Cretaceous and Paleocene source rocks similar to those in the Crazy Mountains Basin, and have demonstratable large basin-centered gas accumulations. Based on analogous comparisons, a basin-centered gas accumulation probably began to develop in the Crazy Mountains Basin during the later stages of basin subsidence, near the end of the Paleocene, due to burial heating. Thermal maturities were elevated further by an Eocene igneous event that produced intense heating in the vicinity of stocks and dikes as well as a low-grade, more regional heating across much of the basin. This heating event is similar to one that affected the Raton Basin in Colorado and New Mexico in Oligocene and Miocene time, which elevated thermal maturities but left the coalbed methane and basin-centered gas accumulation largely intact, and appears to have increased gas content in the coal beds. We suggest that a basin-centered gas accumulation is still present in the deeper parts of the Crazy Mountains Basin away from Eocene intrusions.

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The effect of elevated methane pressure on methane hydrate dissociation

Methane hydrate, equilibrated at P, T conditions within the hydrate stability field, was rapidly depressurized to 1.0 or 2.0 MPa and maintained at isobaric conditions outside its stability field, while the extent and rate of hydrate dissociation was measured at fixed, externally maintained temperatures between 250 and 288 K.

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E&P Focus Vol. 1, No. 2

Technology advances, higher oil prices, reduced costs, and environmental needs have aligned to create a ?perfect storm? of growth opportunity for a well-established method for enhancing oil recovery (EOR) in the U.S.: carbon dioxide (CO2) flooding. The U.S. Department of Energy is supporting critical research to help America's oil producers take full advantage of that growth opportunity (see table on p. 3). CO2 flooding is the fastest-growing EOR technique in the U.S. While production volumes and the number of projects for thermal, chemical, and other EOR processes have fallen off sharply since 1980, the number of CO2 projects has more than tripled, to more than 70 projects as of yearend 2004. Meanwhile, CO2 production volumes have jumped twentyfold since the early 1980s (see chart on p. 2). The CO2 share of U.S. crude oil production was estimated at almost 206,000 barrels per day in 2004, according to the Oil & Gas Journal's biennial EOR Survey, published April 12, 2004. That equals about 4% of the Nation's total. With the proper incentives, CO2 EOR output has the potential to double by 2010 and quadruple by 2020, according to an analysis by the National Energy Technology Laboratory (NETL).

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Integrated Multi-Scale Characterizations of Imbibition and Wettability Phenomena Using Magnetic Resonance and Wide-Band Dielectric Measurements

The objectives of the proposal are to develop methods for obtaining realistic configurations of two immiscible fluids as a function of wettability and geologic characteristics and use these fluid configurations as a basis for predicting and explaining macroscopic (core-scale) behavior, including the relationship between relative permeability, wettability and laboratory and log measurements of NMR and broadband dielectric response. The ultimate objective is to measure dielectric and NMR responses in a range of sedimentary rocks and to use state-of-the-art multi-scale modeling to interpret these measurements to quantify wettability and relative permeability at the core and log scales.

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Recoverable Oil May Add 43 Billion Barrels to U.S. Supply

A series of reports released today indicate there is a potential to meet the demand for an energy thirsty nation by recovering over 43 billion barrels of  additional oil from currently "stranded" oil resources in six regions of the United States, according to an announcement by the Department of Energy's Office of Fossil Energy. Developing these resources would provide significant revenues to state treasuries, provide thousands of additional domestic jobs, and improve the U.S. trade balance by reducing imports.

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DRILLING RESEARCH PROJECTS ADVISORY BOARD MEETING

This report is submitted to summarize TUDRP's research activities since our last meeting in November, 2004. This book contains: ?? an agenda; ?? a list of our member companies; ?? a list of TUDRP’s personnel; ?? a list of our current graduate students, their reports and/or proposals. All reports will be fully presented and discussed at the meeting on May 23rd and 24th, 2005. The active technical and financial support provided by each of you has been the key to our success. With your support and dedication, TUDRP will always strive for academic excellence, high quality research, and will maintain its commitment of providing short and long term drilling technology needs to the oil and gas industry. On behalf of The University of Tulsa, I would like to extend my genuine appreciation for your continued interest in and support of TUDRP.

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The Influence Of Tectonics On The Potential  Leakage Of CO2 From Deep Geological Sequestration Units In The Williston Basin

Leakage of CO2 out of a geological storage site is a major concern associated with sequestration of CO2 in the subsurface as, clearly, any release to the atmosphere would limit the effectiveness of the sequestration effort. Thus, it is important to ensure that long term sequestration is not only feasible, but that the CO2 remains in the geological units into which it is injected.

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