AndreaBozzo/ceres-open-data-index huggingface dataset:
An Experimental Study and Modeling of the Effect of Hydraulic Vibrations on Axial Force Transfer in Horizontal Wellbores

Nowadays, extending the reach is one of the main challenges for operators due to the need to drill more challenging wells. Frictional losses, due to torque/drag or due to buckling, are a primary limitation in extending the reach of many high angle wells. For coiled tubing, owing to inability to rotate the CT, one of the main limitations is the poor axial force transfer and therefore inadequate weight on bit which in turn results in decreased rate of penetration and, as a consequence, increasing drilling cost per foot. For casings and tubulars, excessive drags can lead to inability to slide tubulars for oriented drilling or failure to land a casing or completion string. This paper presents a study and an investigation of a new technique to extend the reach using hydraulic vibrations that can be applicable to coiled tubing; casing, liner and screen running operations; completion tubing running; perforating and intervention. Most important, due to the tighter legislations restricting the use of highly lubricating oil based and synthetic based drilling fluids and due to our need for a cleaner environment, this friction reduction technique is very environmental friendly where oil based lubricants and friction reducers are not needed. In the previous report (May 23, 2005) an approach to reduce the problem of friction between coil tubing and wellbores was presented. The effect of hydraulic vibrations, induced by using a solenoid type valve, on the friction was experimented. Preliminary experiments showed a decrease in the friction force between the pipe and the wellbore. These experiments were conducted by keeping the length of the helically buckled pipe constant through the  duration of vibrations and by not keeping the applied load constant. In this report, a literature review of the fluid structure interaction and the dynamics of the pipe as well as the preliminary steps of the model are presented. Experiments were conducted by trying to keep the top load (applied load) constant through the duration of vibrations. The results of this study are useful for non rotating strings.

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Study of Cuttings Transport with Foam under Elevated Pressure and Elevated Temperature Conditions

This report presents the results and analysis on the study of foam rheology and cuttings transport with foam at Elevated Pressure and Elevated Temperature (EPET) conditions. Foam rheology was measured with two apparatuses, i.e., Foam Generator and Viscometer (FGV), and Advanced Cuttings Transport Facility (ACTF, a large-scale flow loop). Foams were generated using three different concentrations (0, 0.25%, and 0.5%) of hydroxylethylcellulose (Klean-Vish, HEC) and 1% commercial surfactant (K lean-foam). Foam rheology experiments were firstly conducted using a flow-through rotational viscometer with both smooth and roughened cups and rotors. The Foam Generator generates foam with controllable properties and allows the foam to flow through a modified Couette-type rotational viscometer, inside which the rheology is measured. Foam rheology experiments were also conducted using the ACTF, which permits foam flow through both 2?, 3? and 4? pipe sections, and a 5.76? ? 3.5? annular section. During the experiments, frictional pressure losses across the pipe and annular sections were measured for different gas/liquid flow rates and foam qualities (70%, 80% and 90%). A set of rheological parameters were obtained for foams with different qualities and polymer concentrations. Significant rheological variations were observed between aqueous foams containing no polymers and polymer-thickened foams. The cuttings carrying capacity of different foams were also tested, foam cuttings experiments were conducted to determine the effects of polymer additives, foam quality, flow velocity, temperature and pressure on foam cuttings transport. Experiments were carried out at elevated pressure (100psi to 400psi) and temperature (80?F to 170?F) conditions in the annular test section (73- ft long, 5.76? ? 3.5? concentric annulus) of the ACTF. The results show that annular flow velocity, foam quality and polymer concentration all have pronounced effects on cuttings transport and frictional pressure loss. Two flow patterns, stationary cuttings bed with a dispersed layer and fully suspended flow, were observed during the foam cuttings transport tests in the horizontal annulus. Two mathematical models have been developed, which are: i) a foam flow hydraulic simulator in a three segment wellbore, and ii) a mechanistic model for cuttings transport, which combines foam hydraulics and particle rolling equations. The cuttings transport simulator can be used to predict cuttings volumetric concentration in the annulus. The foam flow hydraulic simulations indicate that adding polymer into foam fluid significantly increases Bottom Hole Pressure (BHP). The predictions were compared with cuttings transport with foam experiments using the ACTF, and the model predictions are in agreement with measured data.

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IMAGING RESERVOIR QUALITY: SEISMIC SIGNATURES OF GEOLOGIC PROCESSES

This study documents the similarity in the rock physics patterns of sand-rich deep water deposits from offshore Gulf of Mexico and other similar depositional environments. Lithofacies successions from diverse depositional environments show distinctive patterns in various rock-physics planes (seismic velocity-porosity, velocity-density and porosity-clay volume). Four clear examples of decameter-scale lithofacies sequences are documented in this study: (1) fluvial deposits from the Miocene of Colombia show an inverted-V pattern indicative of mm- to cm-scale dispersed fabric in the mixed lithofacies, (2) a fining-upward lithofacies sequence of mud-rich deep water deposits from offshore West Africa shows a linear trend associated with mm- to cm-scale horizontally laminated sand-clay mixtures, (3) sand-rich deep water deposits from offshore Gulf of Mexico present a pattern resulting from the scarcity of mixed lithofacies, and (4) a coarsening-upward lithofacies sequence of shallow marine deposits from Colombia presents evidence of both dispersed and horizontally laminated mixed lithofacies, with predominating dispersed mixtures generated by bioturbation..

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

The project goal is to develop, through basin analysis, the concept that petroleum systems acting in a basin can be identified through basin modeling. The specific objective is to demonstrate that the information and analysis resulting from the characterization and modeling of petroleum systems in the North Louisiana Salt Basin and the Mississippi Interior Salt Basin can be used to provide a reliable and advanced approach for targeting stratigraphic traps and specific facies associated with a geologic system and providing a refined assessment of undiscovered and underdeveloped reservoirs and associated resources.

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Carbon-Dioxide-Enhanced Oil Production from the Citronelle Oil Field in the Rodessa Formation, South Alabama

The work to be done has the following components, with the organizations having the relevant expertise and resources identified in parentheses following each topic: 1. Communication and Technology Transfer (University of Alabama and University of Alabama at Birmingham), 2. Geology and Petrology (Geological Survey of Alabama and Southern Company), 3. Reservoir Fluid Properties and Phase Behavior (University of Alabama), 4. Petroleum Reservoir Simulation (University of Alabama), 5. CO2 Liquefaction, Transportation, and Storage (Southern Company and Denbury Resources), 6. Well Preparation and CO2 Injection (Denbury Resources), 7. Surface Monitoring (Alabama A&M University), 8. Seismic Monitoring (University of North Carolina at Charlotte), 9. Saline Formation Simulation (University of Alabama at Birmingham), 10. Visualization of Geologic Structure and Flows (all partners), and 11. Reservoir Management Plan and Economic Analysis (all partners). Subcontracts for the second year of work by the partners will be placed during January 2008.

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Fluid-Rock Characterization for NMR Well Logging and Special Core Analysis

NMR well logging provides a record of formation porosity, permeability, irreducible water saturation, oil saturation and viscosity. In the absence of formation material, the NMR logs are interpreted using default assumptions. Special core analysis on core samples of formation material provides a calibration between the log response and the desired rock and/or fluid property. The project proposes to develop interpretations for reservoirs that do not satisfy the usual assumptions inherent in the interpretation. Also, NMR will be used in special core analysis to investigate the mechanism of oil recovery by wettability alteration and the relative permeability of non-water-wet systems.

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Application of Time-Lapse Seismic Monitoring for the Control and Optimization of CO2 Enhanced Oil Recovery Operations

This project is being conducted in two phases. The objective of the first phase is to characterize the reservoir using advanced evaluation methods in order to assess the potential of a CO2 flood of the target reservoir. This reservoir characterization includes advanced petrophysical, geophysical, geological, reservoir engineering, and reservoir simulation technologies. The objective of the second project phase is to demonstrate the benefits of using advanced seismic methods for the monitoring of the CO2 flood fronts.

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Demonstration of a Novel, Integrated, Multi-Scale Procedure for High-Resolution 3D Reservoir Characterization and Improved CO2-EOR/Sequestration Management, SACROC Unit

The primary goal of this project was to demonstrate a new and novel approach for high resolution, 3D reservoir characterization that can enable better management of CO2 enhanced oil recovery (EOR) projects and, looking to the future, carbon sequestration projects. The approach adopted has been the subject of previous research by the DOE and others, and relies primarily upon data-mining and advanced pattern recognition approaches. This approach honors all reservoir characterization data collected, but accepts that our understanding of how these measurements relate to the information of most interest, such as how porosity and permeability vary over a reservoir volume, is imperfect. Ideally the data needed for such an approach includes surface seismic to provide the greatest amount of data over the entire reservoir volume of interest, crosswell seismic to fill the resolution gap between surface seismic and wellbore-scale measurements, geophysical well logs to provide the vertical resolution sought, and core data to provide the tie to the information of most interest. These data are combined via a series of one or more relational models to enable, in its most successful application, the prediction of porosity and permeability on a vertical resolution similar to logs at each surface seismic trace location.

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Improvement Of Carbon Dioxide Sweep Efficiency By Utilization Of Microbial Permeability Profile Modification To Reduce The Amount Of Oil Bypassed During Carbon Dioxide Flood

The objective of this project is to significantly improve oil recovery at Eucutta Field, Wayne County, Mississippi and Little Creek Field, Lincoln and Pike counties, Mississippi by combining an established procedure, carbon dioxide flood, with a new technology, microbial permeability profile modification (MPPM), developed at Mississippi State University (MSU) under prior DOE contract. MPPM technology, which utilizes environmentally friendly nutrient solutions to simulate the growth of the indigenous microflora in the most permeable zones of the reservoir, is compatible with the use of carbon dioxide, which is diverted to less permeable, previously unswept zones of the reservoir, thus improving production.

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Imaging Super-Deep Gas Plays Across the Gulf of Mexico Shelf with Multicomponent Seismic Technology

This project will demonstrate the ability of a new seismic technology to image super-deep gas targets across congested production areas of the shallow-water shelf of the Gulf of Mexico (GOM). The technology being tested uses seismic sensor cables that are deployed on the seafloor. Ocean-bottom sensors can be deployed close to platform legs, wellheads, and other obstacles, allowing complete flexibility in placing receiver stations where they will result in optimal imaging. This creates the ability to improve the imaging of super-deep (30,000 ft) geologic targets.

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Improvement Of Carbon Dioxide Sweep Efficiency By Utilization Of Microbial Permeability Profile Modification To Reduce The Amount Of Oil Bypassed During Carbon Dioxide Flood

This innovative project seeks to link an established procedure, carbon dioxide (CO2) water-after-gas (WAG) flood, with a new technology, microbial permeability profile modification (MPPM), developed at Mississippi State University (MSU) under a prior DOE contract.

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Carbon-Dioxide-Enhanced Oil Production from the Citronelle Oil Field in the Rodessa Formation, South Alabama

The principal objective of the project is to provide the geologic and reservoir engineering analysis and field testing that will permit the operators of the Citronelle Oil Field to successfully apply CO2-EOR to increase oil recovery and extend the productive life of the field. The project will proceed from the analysis of existing well logs to determine, in the greatest detail possible, the structure of the Rodessa Formation in the vicinity of the Citronelle Field, through seismic measurements to improve spatial resolution of the stratigraphy and movement of CO2, to a demonstration of increased production from the wells. A second objective is to establish and transfer to industry the engineering expertise with which apply CO2-EOR at other sites having geologic structure similar to that of the Rodessa Formation, which is very different from the Permian Basin structure where CO2-EOR is a well established and successful tertiary oil recovery technology.

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Combined Borehole Seismic and Electromagnetic Inversion For High-Resolution Petrophysical Assessment Of Hydrocarbon Reservoirs

This report summarizes the work performed between January 2005 and December 2007, under DOE research contract DE-FC26-04NT15507. The project is was performed by the Center for Petroleum and Geosystems Engineering of The University of Texas at Austin and Lawrence Berkeley National Laboratory under the auspices of the National Energy Technology Office (NETL) and the Strategic Center for Natural Gas and Oil (SCNGO).

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Carbon-Dioxide-Enhanced Oil Production from the Citronelle Oil Field in the Rodessa Formation, South Alabama

The work being done has the following components, with the organizations having the relevant expertise and resources identified in parentheses following each topic: 1. Communication and Technology Transfer (UA and UAB), 2. Geology and Petrology (GSA and Southern Company), 3. Reservoir Fluid Properties and Phase Behavior (UA), 4. Petroleum Reservoir Simulation (UA), 5. CO2 Liquefaction, Transportation, and Storage (Southern Company and Denbury Resources), 6. Well Preparation and CO2 Injection (Denbury Resources), 7. Surface Monitoring (AAMU), 8. Seismic Monitoring (UNCC), 9. Saline Formation Simulation (UAB), 10. Visualization of Geologic Structure and Flows (all partners), and 11. Reservoir Management Plan and Economic Analysis (all partners).

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Carbon-Dioxide-Enhanced Oil Production from the Citronelle Oil Field in the Rodessa Formation, South Alabama

The work being done has the following components, with the organizations having the relevant expertise and resources identified in parentheses following each topic: 1. Communication and Technology Transfer (all partners), 2. Geology and Petrology (GSA and Southern Company), 3. Reservoir Fluid Properties and Phase Behavior (UA), 4. Petroleum Reservoir Simulation (UA), 5. CO2 Liquefaction, Transportation, and Storage (Southern Company and Denbury Resources), 6. Well and Site Preparation and CO2 Injection (Denbury Resources), 7. Surface Monitoring (AAMU), 8. Seismic Imaging (UNCC), 9. Saline Formation Simulation (UAB), 10. Visualization of Geologic Structure and Flows (all partners), and 11. Reservoir Management Plan and Economic Analysis (all partners).

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DOE/NETL IGCC Dynamic Simulator Research and Training Center Volume 2: IGCC Process Descriptions

Volume 2 The generic IGCC power plant produces 746 MW gross (556-megawatt net) electric power and consists of dual-train gasifiers producing clean singes for combustion in two (2) F-class advanced combustion turbines with a combined net output of 464 MW. The exhaust of each combustion turbine (CT) is sent through a heat recovery steam generator (HRSG) and produces steam that is supplied to a steam turbine (ST) having a net output of 275 MW. A syngas expander supplies an additional 6.3 MW of net output. This document provides a conceptual design of the DOE/NETL IGCC Dynamic Simulator reference plant. In this context, conceptual design means that all of the major components and systems and the relevant control loops have been defined. The basis of the simulator conceptual design is the engineering model of the IGCC Power Plant included as Case 2 in the DOE / NETL?s report ?Cost and Performance Comparison of Fossil Energy Power Plants Volume 1, Bituminous Coal and Natural Gas to Electricity Final Report (DOE/NETL-2007/1281), Rev. 1 August 2007.? A Process Flow Diagram of Case 2 is presented below in Figure 1.

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Imaging Reservoir Quality: Seismic Signatures of Geologic Processes

Lithofacies successions from diverse depositional environments show distinctive patterns in various rock-physics planes (velocity-porosity, velocity-density and porosity clay). Four clear examples of decameter-scale lithofacies sequences are documented in this study: (1) Micocene fluvial deposits show an inverted-V pattern indicative of dispersed fabric, (2) a fining-upward sequence of mud-rich deep deposits shows a linear trend associated with laminated sand-clay mixtures, (3) sand-rich deposits show a pattern resulting from the scarcity of mixed lithofacies, and (4) a coarsening-upward sequence shows evidence of both dispersed and horizontally laminated mixed lithofacies, with predominating dispersed mixtures generated by bioturbation.. It was observed that carbonate-cemented sandstones are extremely heterogeneous in the project deep-water study area. Those from the base of incisions are usually associated with lower shaliness, lower porosity and higher P-impedance, while from the top of flooding surfaces exhibit higher shaliness, higher porosity and lower P-impedance. One rock physics model that captures the observed impedance-porosity trend is the “stiff-sand model.” For this model, the high-porosity end-member is unconsolidated sand whose initial porosity is a function of sorting and shaliness, while the low-porosity end-member is solid mineral. These two end points are joined with a Hashin-Shtrikman equation. A systematic variation of quartz: clay ratio from proximal to distal locations was observed in the study area even within a single facies. The quartz: clay ratio changes from [0.5:0.5] to [1:0] along the direction of flow, based on the trends of P-impedance vs. porosity as predicted by the rock model for uncemented sands. The results are in agreement with spill-and-fill sequence stratigraphic model in mini-basin setting. In addition, porosity at the distal location (~25 % to 35%) is higher than the porosity at the proximal location (~20 % to 23%). This trend is explained by a sequence stratigraphic model which predicts progressive increase in sorting by turbidity current along the flow, as well as, quantified by a rock model that heuristically accounts for sorting. The results can be applied to improve quantitative predication of sediment parameters from seismic impedance, away from well locations.

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GTI Unveils New Laser Laboratory for E&P Research

Gas Technology Institute (GTI) today unveiled a new research facility at its Des Plaines headquarters campus for evaluating the use of laser energy to improve various well construction and completion processes. Laser technology holds significant promise as a less costly and more efficient alternative to rotary drilling for constructing gas and oil wells and for related processes that prepare wells for operation. GTI has studied several military laser systems for possible use as an alternative to rotary drilling in constructing wells. Tests from 1997 to 1999 showed that these megawatt-size lasers have more than enough power to break, melt, or vaporize rock, penetrate rock more rapidly than conventional drilling, and even increase the permeability of rock, which would improve gas flow from the surrounding formation into a wellbore.

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DOE's Enhanced Oil Recovery Program An Archive of Important Results

Primary and secondary oil production recovers on average about 40% of the original oil in place (OOIP) in oil reservoirs. The remaining oil (currently about 400 billion barrels in the U.S.) is a target for enhanced oil recovery (EOR) methods. The Department of Energy's (DOE) research related to EOR has focused on developing advanced technology, providing a greater understanding of EOR, and transferring technology to aid industry in recovering a greater portion of this important domestic energy resource.

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Treating Coal-Bed Methane Produced Water for Beneficial Use by MFI Zeolite Membranes

This report describes work performed during Phase II of the project ?Treating Coalbed Natural Gas Produced Water for Beneficial Use by MFI Zeolite Membranes.? Ion separation by MFI-type zeolite membranes was successfully demonstrated in our previous work (Phase I). The pure silicalite membranes synthesized by in-situ crystallization show high ion separation efficiency (>90%) but low water flux (~0.12 kg/m2.h). The main challenge revealed in our previous study is how to enhance the water flux and to scale up this material for practical application. The work in Phase II attacks these difficult problems, targeting synthesis of high flux zeolite membranes with enhanced water flux and development of post-synthesis modification. Several efforts have been made in Phase II to enhance the water flux and ion rejection, as well as to improve the reproducibility of zeolite membranes.

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Carbon-Dioxide-Enhanced Oil Production from the Citronelle Oil Field in the Rodessa Formation, South Alabama

The work to be done is viewed as having the following components, with the organizations having the relevant expertise and resources, and best suited to lead the planning and execution of the work, identified in parentheses following each topic: 1. Communication and Technology Transfer (University of Alabama and University of Alabama at Birmingham), 2. Geology and Petrology (Geological Survey of Alabama and Southern Company), 3. Reservoir Fluid Properties and Phase Behavior (University of Alabama), 4. Petroleum Reservoir Simulation (University of Alabama), 5. CO2 Liquefaction, Transportation, and Storage (Southern Company and Denbury Resources), 6. Well Preparation and CO2 Injection (Denbury Resources), 7. Surface Monitoring (Alabama A&M University), 8. Seismic Monitoring (University of North Carolina at Charlotte), 9. Saline Formation Simulation (University of Alabama at Birmingham), 10. Visualization of Geologic Structure and Flows (all partners), and 11. Reservoir Management Plan and Economic Analysis (all partners). Subcontracts with the Geological Survey of Alabama and all of the university partners, except the University of North Caroline at Charlotte, are in place.

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