bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhanced Nozzle Inflow Control Device Development for Wall Shear Stress Minimization in High-Production Application
Authors: Corona Georgina , Yin Weiqi , Felten Frederic 
Published: April 2016

Abstract
Inflow control devices (ICD) are a proven technology for overall production flux balance. Because they restrict flow, standard ICDs develop regions of high-fluid velocities and high-wall shear stresses. Wall shear stress is a tangential drag force produced by a layer of flow along a wall as a result of friction between the fluid and the wall. Elevated production rates of oil and/or water with CO2 or H2S increase fluid velocities and associated wall shear experienced by ICDs potentially leading to flow-induced erosion-corrosion and mechanical failure. For these environments, corrosion is enhanced by the removal of the passivating layer through fluid flow-induced erosion.
Because of the strong need for ICD completions in a high profile field project in the Middle East, an enhanced ICD design has been developed to withstand high production rates without creating high wall shear, thus reducing erosion-corrosion induced by flow. Computational fluid dynamics (CFD) was used to study several ICD designs and assess the modifications necessary to enhance performance for different flow rates and pressure drop conditions. Worst case scenarios were evaluated to ensure the modified design would be suitable for the environment and meet the operator's criteria for production.
CFD analysis proved the enhanced adjustable nozzle ICD was an improvement over the standard ICD. This modified design showed lower wall shear on the critical surfaces. Throughout the ICD design optimization process, flow behavior was evaluated to minimize regions of predicted high velocity and wall shear. The enhanced design is commercially available in the Middle East. The modified, adjustable, nozzle ICD helps to condition the flow better than the standard ICD, thus reducing the wall shear stress around critical parts (including perforation holes, basepipe surface, and NPT plugs). This reduction is crucial when dealing with required high production flow rate.
Exploring options to minimize wall shear stress on the surfaces of completion components is a relatively recent challenge. It is an important subject for operators attempting to avoid mechanical failures and the associated recompletion costs. The present study provides a methodology to design fluid passages to minimize the flow-induced erosion-corrosion experienced at high production rates as well as high injection rates experienced during workover operations.
Human Factors and Organizational Management - Can We Fix the Mindset? Modernizing Drilling with Human-Centered Designs
Authors: Hoffmann K. J. , Gutierrez J. A. 
Published: April 2016

Abstract
Engineers cannot fix an industry mindset, but they can offer possible solutions to enhance product design and assist with improved operations. One such solution, which has been applied in multiple industries have incorporated Human-Centered Design (HCD) to improve safety integrity, reduce downtime and increase efficiency. HCD incorporates better user interfaces and system design that can assist users when critical decisions must be made. Proper human-centered design or HCD can reduce stress and errors. The application of HCD best practices has helped multiple industries improve safety integrity, reduce downtime, and increase efficiency.
This paper will discuss how employing a HCD process—characterized by the active involvement of users, appropriate allocation of function between users and technology, iteration of design solutions, and a multidisciplinary design team—may result in products for offshore installations that could contribute to a reduction in downtime by utilizing easier to understand formats that may enhance user productivity, and improve operational efficiency.
Applied Geostatistical Reservoir Characterization in R: Review and Implementation of Permeability Estimation Modeling and Prediction Algorithms - Part II
Authors: Al-Mudhafar Watheq J. 
Published: April 2016

Abstract
Modeling and prediction the formation permeability is a decisive step in the reservoir characterization as it concerns the sparseness of the row data with different scales from different sources. Efficiently combining the different sources of rock characteristics, especially core and well logs data, should lead to accurate estimation of permeability for other wells that have no core analysis. That results in accurate reservoir characterization, precise geospatial modeling and solid reservoir modeling.
The most conventional approach for combining the core measurements, well log data into permeability modeling is the Multiple Linear Regression, which considers the least-square equation to estimate the coefficient of parameters in the linear modeling. However, there are many other algorithms that can be used for more accurate modeling and prediction of formation permeability. The other methods include: Multivariate Multiple Linear Regression, Generalized Additive Modeling, Multivariate Adaptive Regression Splines, Least-Angel Regression, Bayesian Generalized Linear Modeling, and Robust Linear Modeling.
In this paper, review of all the aforementioned algorithms were provided along with full implementation on the permeability modeling given the well log and core data in a well from Rumaila dataset, from South Rumaila oil field in Iraq. The comparison between these agorithms were performed based on the root mean square prediction error of the predicted permeability after conducting data sampling and cross-validation.
These algorithms can be carried out through several commercial software packages with limitations in terms of availability and computation time consuming. In this paper, we introduce a simplified implementation of all these algorithm through R, the most powerful open-source statistical computing language. Detailed R-codes were prepared for all algorithms.
Integrating Rock Physics Modeling, Pre-Stack Inversion and Bayesian Classification: A Gulf of Mexico Case Study
Authors: Russell Brian 
Published: April 2016

AbstractIn this talk, I will directly link the detailed rock physics modeling of a condensate reservoir from the Gulf of Mexico to the pre-stack elastic inversion results from this reservoir and the Bayesian classification of these results. The goal of this study is to provide a quantitative link between these three very important aspects of seismic reservoir modeling: rock physics, elastic inversion and classification. The first step in this procedure is to perform pre-stack inversion of a 3D seismic volume recorded over the condensate reservoir using available well data, Biot-Gassmann modeling and the interpreted seismic picks as a starting model. Next, I identify the various lithological units from the inversion results and cross-plot these results using VP/VS ratio versus P-impedance. I then compare the cross-plot of the inverted results to the cross-plot of the well log after Biot-Gassmann modeling, in the same parameter space. I next build a detailed rock physics model of the reservoir and perturb the parameters in this model to obtain a good fit to the extracted inverted results. Finally, I use Bayesian classification to identify the probabilistic extent of the reservoir. The significance of this work is that a workflow has been developed, and applied to a Gulf of Mexico dataset, which allows us to iteratively tie together all aspects of quantitative seismic reservoir analysis, from rock physics modeling through elastic inversion to Bayesian classification.
An Innovative Packaged Gas Solution to Optimize Supply Chain
Authors: Mangeot-Gehin N. , Robertson S. , Arnaud G. 
Published: April 2016

Abstract
An innovative solution to help optimize operations for industry and to deliver improved performance and efficiencies across all its activities enhancing asset efficiency and safety, for Industrial gases used Offshore.
Safety is a top priority for the oil and gas industry, and Air Liquide has extended above and beyond industry safety standard compliance with the creation of its latest product.
Operators deploy industrial gases on a daily basis across all aspects of both upstream and downstream activities. This includes pipe fabrication and laying, construction, commissioning and decommissioning of offshore infrastructures, commercial diving for inspection maintenance and repair of subsea structures and well services such as inerting, coil tubing, pigging, and underbalanced drilling.
The oil and gas industry is renowned for its commitment to technological innovation to increase efficiency and optimise performance. These factors, aligned with customer demand, were the guiding principles behind Air Liquide’s decision to create the definitive quad, incorporating extreme performance, enhanced ergonomics and the most advanced safety features in the world.
A new packaged gas solution was launched in September 2015 following rigorous design, and safety and compliancy testing processes. It is already attracting significant attention from major operators who can see the benefits of being able to store and distribute gas in a safer and more efficient way.
The technology serves the major activities of construction and maintenance, subsea works and well services and combines a 40% gas capacity increase, an intuitive human-machine interface (HMI) and advanced safety features such as a built-in pressure reducer with an on/off lever.
Measurement Procedures and Analysis of Fluid Invasion Drivers During Cement Hydration
Authors: Silva Emilio C. C. M. , Jandhyala Siva Rama Krishna , Bardapurkar Sameer , Palla Venkata Gopala Rao , Ravi Kris , Singh Sheetal , Pearl William 
Published: April 2016

Abstract
Fluid invasion during cement hydration is governed by, among other factors, differential pressure between the formation fluids and the annular fluid. The primary phenomena influencing pressure in the annulus are evolution of cement slurry physical and chemical properties with time, filtrate lost to the formation, and changes in cement slurry volume during hydration. A successful procedure to design slurries to mitigate fluid invasion shall model these phenomena and provide viable methods to measure model parameters. At the same time, it should be feasible to formulate cement slurries to obtain the parameters necessary for a successful design.
This paper discusses model details with emphasis on parameters, their test procedures, and equipment details. Dynamic filter-cake properties are calculated by applying compressible filtration theory on data from a modified fluid loss test. Shrinkage/expansion is measured under temperature using the API ring mold apparatus. Pressure and displacement response to filtrate loss and shrinkage/expansion is dependent on bulk modulus, shear modulus, and static gel strength (SGS) evolution of the cement slurry during hydration. Properties are measured as a function of time using sonic analysis and a rotational gel strength device. Both material properties and volume changes attributed to fluid loss and hydration showed time dependency.
Furthermore, the pressure response of two realistic wells having different permeability and pore pressure profiles is analyzed. The two analyzed wells had different pressure responses, indicating that the slurry design should be customized for each well. This difference is attributed to varying capabilities of the well to compensate for volume loss by movement of cement placed adjacent to the permeable section, showing that the relative locations of the filtrate loss and potential fluid influx zones are important. Such an observation is possible only because of the ability to measure and model dynamic properties and events. The proposed methods are practical and can be realized using existing equipment with few procedural changes. Analysis based on these measurements guides the customization of slurry designs.
An Integrated Approach for Characterizing a Sandstone Reservoir in the Anadarko Basin
Authors: Ampomah W. , Balch R. S. , Ross-Coss D. , Hutton A. , Cather M. , Will R. A. 
Published: April 2016

Abstract
This paper presents field scale reservoir characterization of the Farnsworth field unit undertaken as part of a Phase III project conducted by the Southwest Regional Partnership on Carbon Sequestration. Farnsworth Unit (FWU) is located on the northwest shelf of the Anadarko Basin. The target unit for CO2 injection, storage, and enhanced oil recovery (EOR) is an upper Morrow sandstone informally named the Morrow B Sand.
The Morrow B reservoir was deposited during early Pennsylvanian time as incised valley fill fluvial sands. Core and thin sections were examined to determine lithology, mineralogy, porosity types, depositional environment and diagenetic history. Data from XRD analysis, optical and scanning electron microscopy, and microprobe analysis were compared with results from an elemental log analysis (ELAN). This information, together with additional core, well log, borehole image log, vertical seismic profile and 3D surface seismic data was used to characterize and subsequently create a fine scale lithofacies-based geological model of the field. Structural modeling was based on integration of 3D seismic and compressional sonic well log data to create a velocity model convertin the seismic z-axis into the depth-domain. Converting domains allowed the 3D seismic data to be correlated to other depth-domain datasets, such as new and legacy well log data and core sections. Seismic attributes were able to illuminate previously unknown faults and structural elements within the field.
During the petrophysical modeling, several deterministic and stochastic techniques were compared and analyzed to ascertain which method best populates the geological properties into the model. These techniques included kriging, sequential Gaussian simulation (SGS) and Gaussian random function simulation (GRFS). A data analysis approach was used as a quality check to reduce uncertainty in the modeling. Studies of depositional environment provided data used constructing porosity—permeability crossplots; this proved to be a useful approach to assigning permeability to the lithofacies-based geological model. The accepted static model was upscaled for dynamic reservoir simulation.
The approach illustrated in this study presents an improved methodology in characterizing heterogeneous and complex reservoirs that can be applied to reservoirs with similar geological features.
Comparison of the Seismic Response of Offshore Slopes Using 1, 2, or 3 Ground Motion Components
Authors: Carlton Brian D. , Kaynia Amir M. 
Published: April 2016

AbstractOffshore landslides pose a major threat to subsea facilities, and one of the main triggering factors of offshore landslides is strong earthquakes. The state of the practice models offshore slope stability during strong shaking using one horizontal component of a selected representative ground motion. However, slopes and earthquakes are three-dimensional phenomena. Therefore, to provide much needed guidance in this area, this study performed 27 three-dimensional seismic slope stability analyses in a finite element program to investigate the change in the predicted results when applying one, two, or three ground motion components.The results showed that applying two horizontal components instead of one may increase the predicted total displacements and shear strains on the slope by 25% to 50% and by 10% to 50%, respectively. In addition, it may also increase the total displacements at the seafloor on the shelf above the slope by 20% to 40%. This could have implications when deciding the safe stand-back line for offshore facilities. However, applying three ground motion components has a negligible effect on the results compared with applying only the two horizontal components. The ratio of the response spectra on the shelf, slope, and basin varied by ± 25%, however no clear trend was observed.
Novel Liquid Foam Stabilizer for Cementing Applications
Authors: Doan Angela Anh , Ejike Mosunmola Omuwunmi , Li Li 
Published: April 2016

Abstract
Deepwater drilling and cementing have been a challenge due to the low temperature at seabed, low fracture gradients, shallow water flow, gas hydrates, etc. Foamed cementing is one of the best practices that have been used for deep water wells. Dry foam stabilizers have been used but are limited to the number of jobs achievable with pre-blended cement on the rig. Introducing a liquid foam stabilizer improves logistics and flexibility, so one type of cement can be used for all cementing jobs, including primary and remedial jobs.
In this study, the performance of the novel liquid foam stabilizer was thoroughly evaluated with different types of cement and mixing fluid at various temperatures. API class H or class G cement with a foaming agent and the new foam stabilizer were mixed with fresh or sea water at different densities. The salt tolerance of the liquid foam stabilizer was investigated by adding a variety of salts at different concentrations. This liquid foam stabilizer also was evaluated at different concentrations and different foam qualities.
The evaluation includes foam stability and density distribution of set cement. Both the set and unset foam stability were tested. The test results show that the liquid foam stabilizer significantly improves the foamed slurry stability and the density distribution of the set cement.
The new liquid foam stabilizer helps foamed slurry and set cement stability with different types of cements, with fresh and sea water at temperatures from 40 to 190°F. In addition, it helps to improve system flexibility and logistics. Land and offshore applications of the new liquid foam stabilizer will also be described in detail.
Development and Qualification of a Subsea 3,000 Barrel Pressure Compensated Chemical Storage and Injection System
Authors: Schroeder Art J. , Chitwood James E. , Krasin Tim , Lee Brian , Krohn Dan , Huizinga Menno , Paramonoff Alex , Schroeder Charlotte , Gay Tom A. , Cercone David , Pappas James 
Published: April 2016

Abstract
This paper presents important findings while executing a detailed qualified design of a large (3,000 + barrel), subsea (to depths of 10,000 fsw) production chemical storage and injection system. The design drivers for the system were safety first, extensive utilization of existing commercially available equipment / tools / methods, and a re-usable shuttle system that allows for delivery of production chemicals as a service versus the current approach where an operator / owner makes a capital investment. The system is designed to be compatible with existing production chemical formulations and features multiple barrier design between the chemicals and the environment. Placement of the storage and injection system directly on the seafloor in close proximity to the point of need eliminates expensive chemical umbilicals, removes significant topside chemical storage and injection kit weight and space requirements at host facility and isolates hazardous chemicals from platform workers. The re-deployable shuttle economically allows inspection, repair and maintenance to take place quayside with the ability to upgrade equipment as technology progresses and / or quickly and cost effectively adjust to ever-changing field requirements.
Subsea wells have been proliferating over the last decade with ever-longer tie-backs to enable commercial recovery of small resource pools that are unable to support a traditional floating system development. Virtually all wells, especially subsea, require various volumes and types of production chemistries during their operational life. For subsea wells, the incumbent technology is chemistry delivery via umbilicals. In rare occasions, small volumes are sometimes delivered via single trip, disposable containers, principally during intervention activities. As tie-back distances have increased, so have the technical challenges with their attendant mushrooming costs. These challenges include the needs for; special corrosion resistant materials, resistance to high pressures differentials, material flexibility and ‘crimp – resistance’, and long term reliability. Additionally, some of these chemicals are high viscosity and as the tie-back distances increase, so does the pressure drop of the flowing fluids. In some cases, the risks of plugging and the magnitude of the delta-pressure drop in ½? – ¾? chemical tubing within the typical umbilical can preclude tie-backs of long offsets from the host / hub facility. The subject system overcomes many of these challenges by locating a large, pressure compensated storage and injection facility directly on the seafloor in close proximity to the point of need, thus qualifying it as enabling technology for extra-long tie-backs and enhancing technology for short tie-backs, de-bottlenecking, or early production system usage.
Microscopic Study of Wax Inhibition Mechanism
Authors: Daraboina Nagu , Soedarmo Auzan , Sarica Cem 
Published: April 2016

AbstractUsage of paraffin inhibitors (PI) is one of the practices, especially in deepwater operation, to reduce pigging frequency. The PI selection process is challenging as their working mechanisms are yet to be fully understood. The understanding of crude specific interactions and the upscaling capability from cold finger testing in laboratory to full field scale is limited. This work emphasizes a microscopic study of paraffin crystals morphology under the influence of polymer based chemical inhibitors. The experiments were performed with three types of PI (A, B, and C), two types of oil (a model oil with 1%-wt. wax and a condensate with 9%-wt. wax), and three different PI concentrations (100, 250, and 500 ppm)For no PI cases, the crystal size between the condensate (CS) and the model oil (MO) are visibly different as MO produces bigger crystals with less nuclei number density than CS. The PI-A (linear co-polymer) is observed to promote formation of larger crystals in both oils, except for 250 and 500 ppm concentrations in CS. The PI-B (long chain comb-like co-polymer) and PI-C (short chain comb-like co-polymer) are observed to generate smaller crystals in both oils, most of the times with greater nuclei number density. The PI-B is more effective in reducing crystal size for CS while PI-C is more effective in MO. An increase in PI concentration does not necessarily magnify the changes in crystal size exhibited in lower concentration. The microscopic characteristics (e.g., crystal size, nuclei number density) of paraffin crystals are expected to affect macroscopic characteristics (thickness and hardness) of the deposit.