bluuebunny/crossref_metadata_2025_split huggingface dataset:
Antemortem diagnosis of hydrocephalus in two Congo African grey parrots (Psittacus erithacus erithacus) by means of computed tomography
Authors: Thurber Mary I. , Mans Christoph , Fazio Constance , Waller Ken , Rylander Helena , Pinkerton Marie E. 
Published: March 2015

Abstract
Case Description—A 7-year-old and a 10-year-old Congo African grey parrot (Psittacus erithacus erithacus; parrots 1 and 2, respectively) were evaluated because of neurologic deficits.
Clinical Findings—Parrot 1 had an 8- to 9-month history of lethargy and anorexia, with a recent history of a suspected seizure. Parrot 2 had a 6-month history of decreased activity and vocalizing, with an extended history of excessive water intake; a water deprivation test ruled out diabetes insipidus, and psychogenic polydipsia was suspected. Both birds had ophthalmologic asymmetry, with anisocoria detected in parrot 1 and unilateral blindness in parrot 2. Metal gastrointestinal foreign bodies were observed on whole-body radiographs of both birds, but blood lead concentrations were below the range indicated for lead toxicosis. Findings on CT of the head were consistent with hydrocephalus in both cases.
Treatment and Outcome—Parrot 1 received supportive care and died 3 months after the diagnosis of hydrocephalus. Parrot 2 was treated with omeprazole and prednisolone for 10 days without any improvement in neurologic deficits; euthanasia was elected, and hydrocephalus was confirmed on necropsy. No underlying or concurrent disease was identified.
Clinical Relevance—Hydrocephalus should be considered a differential diagnosis for parrots evaluated because of CNS signs. Computed tomography was an excellent screening tool to diagnose hydrocephalus in these patients. Compared with MRI, CT is more frequently available and offers reduced scanning times, reduced cost, and less concern for interference from metallic foreign bodies.
Utilizing a Micro-Vacuuming Jet Pump and Concentric Coiled Tubing to Clean Mud Damage and Fill from Wellbores with Small Completion Size and Low Bottom Hole Pressure
Authors: Gunther Owen , Higgins Geoff William , Li Jeff , Lambert Mitchell D. 
Published: March 2015

Abstract
In instances of ultra-low bottom hole pressure (BHP) where the results of conventional cleanout methodologies range from inefficient to ineffective, wellbore vacuuming technology has proven to be a reliable alternative. Technology using concentric coil-in-coil tubing (CCT) design was developed in 1995 and is being used as an effective method to remove both unwanted liquids and solids from wells where formation pressure is prohibitively low for conventional cleanout techniques.
The process involves pumping a work fluid down the internal string through a venturi nozzle assembly. A localized pressure drawdown is created at the bottom hole assembly (BHA), drawing wellbore liquids and solids into the return flow with the work fluid. The combined flow is returned up the outer coiled tubing string to surface. This process does not expose the wellbore to the hydrostatic pressure of the workover fluids.
More than 600 wells have been treated to date with the wellbore vacuuming technology. Recently, the wellbore vacuuming technology has been revisited and extended to smaller internal diameter (ID) completions; this required a BHA and process redesign. Outlined in this paper are details of the research, development and testing of the 1.75" (44.5 mm) micro-vacuuming tool with recommended procedures, design criteria and operational practices for liquid and solids removal. Case histories from shallow gas wells &lt;2,200 ft (670 m) and deep gas wells &gt;10,000 ft (3050 m) with formation pressure gradients as low as 0.03 psi/ft (0.68 kPa/m) are presented. As well, engineering challenges, best practices and lessons learned from the micro-vacuuming process are summarized.

Introduction
Sand production is a common problem faced by many of oil and gas producers worldwide. Although a slotted liner acts as a partial barrier, grading effects at the slots often still result in sand migration into the wellbore and reduce production rates. The low production flow rates contribute to increased deposition of the sand within the wellbore.
Several cleanout options have been developed over the decades employing a number of different techniques approaches.1 However, coiled tubing (CT) or conventional jointed pipe often require the use of high circulation rates, special fluids or reverse circulation techniques to remove the solids. With the use of high rates and high specific gravity water based fluids, conventional sand cleanout methods apply excessive down hole pressure on the formation and result in lost circulation returns in the low formation pressure reservoirs. This makes sand removal virtually impossible and creates damage to the formation. Nitrogen can be used to reduce hydrostatic pressure, but this necessitates a very specific job design and execution and can require large amounts of liquid nitrogen in the case of highly deviated or horizontal wells, which may be located in some remote area.
The (FC)2 Alliance - An Innovation Portal for Research on the Fundamental Controls on Flow in Carbonates
Authors: Agar Susan M. 
Published: March 2015

Abstract
The (FC)2, Alliance is founded on a thematic research framework to address "Fundamental Controls on Flow in Carbonates". The Alliance involves students and professionals in geoscience and engineering in a major oil and gas company and researchers from 10 universities. The Alliance aims to promote technical breakthroughs through the stimulation and co-ordination of multi-disciplinary studies that are being used to explore the boundaries among geoscience and engineering disciplines. It builds on the knowledge and complementary expertise of industry and academic researchers while capturing distinct ideas that develop in different scientific and regional communities. An options approach enables academic and industry researchers to explore potential collaborations at relatively low initial cost to all parties. The Alliance is founded on a clear strategy and research theme, a competitive selection process, diversity, mutual benefits, flexibility and shared risk. Sensitive to the pitfalls of Alliances, a strong emphasis has been placed on Alliance management, including cultural differences and intellectual property concerns. The scale of the Alliance enables innovation through new connections that develop as researchers in different fields identify links under the common research theme. In this way, (FC)2 serves as an innovation portal by bringing people and ideas together. A set of examples is presented to illustrate the ways that these connections have impacted research advances and the variety of mechanisms that are used to promote interactions and collaboration. Beyond tangible research impacts, the Alliance network promotes additional benefits for all parties, including training, career development, recruiting, and broader interactions that provide positive exposure and expanded awareness. The (FC)2 Alliance has already delivered significant benefits to its members. If such entities become more common place, however, there is a need to develop a critical mass of industry scientists with the skills and experience to manage academic-industry interactions.
Data Management Acceleration Project: A Case Study In Doing It Right!
Authors: Perrone Joseph , Priest Mark , Ali Fahad T. 
Published: March 2015

Abstract
This paper provides details on the formulation and execution of the RasGas Company Limited (RasGas) Petroleum Engineering Department's "Data Management Acceleration Project", also known as DMX.
The objective of this project is to install processes that will manage the entire life cycle of subsurface data, from initial capture to utilization. This objective is actually very different from the conventional objective of most data management projects, which seek to capture, QC and load data into a database. The difference between this project and past RasGas projects is due to how this project was originally conceived.
RasGas is a young company which has experienced a more than six-fold growth in the number of wells and an eight-fold increase in gas production since 1999 when production from RasGas' North Field blocks commenced. The amount of subsurface related data generated by this growth has been substantial and requires a wide range of project data stores to handle the diverse data.
These activities required a wide range of specialized applications and databases to support specific technical workflows. These workflows grew organically as the activity grew, with most of the data collection, quality control, and storage processes being very effective, yet ad-hoc. The nature of the workflows required a substantial multi-disciplinary approach.
Most previous RasGas projects tended to concentrate on technology (software applications) and legacy data quality assurance and loading. The focus of the Data Management Acceleration project is on the development of continuous, sustainable processes that handle the data from initial capture through its utilization, with the key criteria being assurance of data quality, and rapid delivery to end users. The technology to be used is of secondary importance.
The project is structured around the treatment of individual data types (e.g. perforations) as "mini-projects". The work breakdown structure for each of these data types is similar, and focused on creating those processes that are the key contributors to the data's life cycle process. This keeps the focus of activity on the desired objective from the project.
The typical project stages normally seen in conventional data management projects are incidental by-products to the creation of these processes, rather than being key deliverables. While most, if not all, of these activities are still performed in the project, they are steps along the way to success, rather than key deliverables.
Geophysical Exploration Technology Of Complex Volcanic Rock Gas Reservoir
Authors: Feng Zhiqiang , Huang Wei , Feng zihui , Zhang Erhua , Liu Chuanping 
Published: March 2015

Abstract
Lithology identification of complex volcanic rock, reservoir prediction with seismic data and identification of volcanic rock lithology and prediction of fluid property in reservoirs using wireline logging are key techniques for volcanic gas reservoir exploration. Up to now, many exploration wells and a large amount of 3D seismic are performed in volcanic gas reservoirs. Practice and theoretical research has establish a series of effective methods of lithology identification and reservoir and fluid prediction by seismic and wireline logging, with much achievement in gas field exploration evaluation and gas reservoir characterization of Xushen Gas Field.

Instruction
Songliao Basin, located in northern China, is the largest and most prolific non-marine oil-bearing basin. It develops two sets of different Cretaceous formations. The lower rifted formation has alluvial fan to deep lake siliclastic sediments and coal beds, and widely developed volcanic rock. The upper depression formation is mainly fluvial-lucustrine sediments. Being a huge oilfield, Daqing Oilfield has oil reservoirs discovered in sandbodies in fluvial and deltaic facies of upper depression formation in 1959, and large gas reservoirs discovered in volcanic rock in lower rifted formations in 2002. Volcanic gas reservoirs have burial depth of 3000m~5500m. High pressured fluid history of the basin causes difficulty for tight glutinite in this depth to form gas reservoir. Compared with siliclastics, volcanic rock has not only variety of lithology types and pore types, but also little research result. Study on field crops and modern volcanoes process establishes structural patterns for different types of volcanoes. Based on core analysis data of large amount of volcanic rock, and combined with wireline logging and gas testing data, a series of exploration techniques including lithology identification and reservoir and fluid prediction are developed for volcanic gas reservoirs[1].

1 Seismic identification technique for volcanic rock body
Difference of eruption periods and scales cause variety of lithology and complexity of depositional structures. Weathering and host rock also cause variety of seismic structures of volcanic rock.
Process For Improved Mercaptan Removal
Authors: Cadours Renaud , Shah Viren , Weiss Claire 
Published: March 2015

Abstract
Removing mercaptans from sour natural gas has always been considered as a challenge. This is becoming an even more important issue with the global trend towards more stringent specifications for commercial gases.
Amines have been extensively used because of their ability to meet the most severe H2S and CO2 specifications and their very high acid gas selectivity over hydrocarbons, but present very limited mercaptans removal performances. They require an additional treatment step to achieve the total sulfur content specification in the exported gas. Hybrid solvents are more efficient in removing mercaptans, but have the disadvantage of poor acid gas selectivity over hydrocarbons, resulting in hydrocarbon losses with the separated acid gases.
Total, taking advantage of its extensive know-how and experience in acid gas removal with amine mixtures, has developed the HYSWEET® process, using a new hybrid solvent formulation allowing simultaneous absorption of acid gases and of mercaptans, with limited coabsorption of hydrocarbons. The solvent was selected at the laboratory scale, with a particular attention given to operation related constraints e.g., cost, corrosion, foaming, degradation…etc. The new solvent's acid gas and mercaptans removal performances were then validated on a pilot rig.
The performance of the HYSWEET® process has been assessed for several field applications, and compared with the performances of conventional amine processes. This allowed evaluating the potential gain achievable by the implementation of the new hybrid solvent. The study leads to identify the application cases for which the new hybrid solvent will allow an economic and complete mercaptan removal without any additional treatment, and a perspective of reduction of the additional treatments for the other cases. Besides an economical mercaptan removal, the new hybrid solvent allows a significant reduction in the energy consumption.
The results of the techno-economic evaluation of the HYSWEET® process have been confirmed during the first successful industrial application at the Lacq sour gas plant in 2008. Half of the gas production is now treated with the hybrid solvent, allowing the plant to achieve high global mercaptans removal.
These results are fully documented in the paper, demonstrating that the newly developed process is a good contender for the development of new sour gas fields to achieve the increasingly stringent commercial gas specifications.
Active WF ( Pattern) Management Through Modern Online Production Data Base Systems Using Classical Techniques : A Case Study On Heavy Oil Fields In South Oman
Authors: Gupta Vipin Prakash , Al-Saadi Faisal Salim , Al-Belushi Abdulaziz Hikal 
Published: March 2015

Abstract
Water flooding has been used successfully in heavy and viscous oil fields since last fifty years. Though characterized by low recoveries and high cost due to adverse mobility ratio, waterflood is still an attractive option before embarking on expensive EOR solutions.
One of the key elements to success of waterfloods in heavy oil is well and reservoir management. This paper illustrates the use of daily production data to set up systems that indicate the health of waterflood through use of classical techniques so that they are readily available on a demand to know basis for any hierarchy of production systems; field pattern, groups, individual patterns etc. The observations and results can then be applied to take proactive measures for preventive management.
To manage water floods in a dynamic scenario, reservoir engineers need to watch them closely, analyze them for anomalous behavioral trends in a continuous fashion and be able to apply remedial measures as they manifest themselves. This can not be done through numerical simulation models, first, because of the high cost and time constraints and secondly because the models usually are highly simplified and are constructed using an average property data.
Numerous techniques have been developed by various people working on waterfloods around the world in last 4 decades. Most of these techniques are in the form of diagnostic plots based on easily available data. This paper is an effort to put many such methodologies in a structured format which will enable the engineer to monitor the floods in a systematic and step wise manner. It is intended to move personnel involved in waterfloods up a learning curve and provide them with a toolset to not only measure but improve the flood efficiency. It will assist reservoir engineer's production technologists and development geologists who are involved in or are contemplating waterflood operations.

Introduction
Reservoirs communicate with engineers through production data. This language, if interpreted correctly can lead the engineer to understand the sub-surface flow process and thereby improve the efficiency of the system. This paper uses only production data with general use software applications like spreadsheet/ data base systems etc to develop tools that help the engineer to understand the message of reservoirs.
The paper reviews and explains in detail along with application on live data, techniques to estimate volumetric sweep efficiency, prediction of pressure response (using net voidage), interpretation of injection behavior (Hall's Plot), predicting water source in a oil producer (WOR techniques), using heterogeneity index to priorities options and prediction of ultimate recovery through X-plot calculations and a host of minor techniques that help in understanding & visualization of waterflood behavior.
Technology And Application Of Recycling Produced Water From Heavy Oil Production To Steam Generators
Authors: Xie Jiacai , Liu Xilin , Xie Wenyan 
Published: March 2015

Abstract:
This paper presented the results of laboratory studies, pilot field tests and field applications of produced water recycling to steam generators, discussed produced water characteristics, removal of oil and suspended solid, hardness and silica. Up to now, 119, 000 m3/d produced water is recycled to steam generators in china, and realized the goal of uniting the economic, environmental and social benefits together.

INTRODUCTION
Heavy oil is an important national strategic resource and the heavy oil in China is mainly produced by steam injection with the annual oil production of about 15 million tons, fresh water consumption of 1.5×108m3 for steam injection and produced water from heavy oil production of 2×108m3. How to effectively treat the produced water and realize cyclic utilization to save energy, reduce emission and protect the environment is an important issue faced both at home and abroad. The recycling of produced water from heavy oil production is an important technology used in oil production to develop cyclic economy and save energy and reduce emission. Because the produced water has complex compositions, many technical problems exist in effectively treating the produced water to be the feed water for steam generators, including oil-water separation, eliminating the hardness of the high temperature, high salinity and high organics producede water, eliminating SiO2 in the produced water, highly siliceous produced water treatment for steam generators use and oily sludge utilization.
Since 1998 when lab research was started, through tests at different levels, five key techniques have been developed: high efficiency demulsifiers and related techniques for oil water separation;produced water hardness elimination by the volume change during the process of alkali regenerating out of the modified weak resinic acids and its features of eliminating pollution and restoring activity;desiliconization of produced water by combining active magnesium oxide and inorganic aluminum salts and organic flocculants;eliminating scale buildup in boilers and improving the technical limit for SiO2 in the feed water by further eliminating the micro scale forming ions in the produced water with chelating resin;making new compounded fuels out of the recycled oily sludge.
The technology has been widely applied in Liaohe Oilfield as well as in Xinjiang, Henan and Shengli Oilfield. Since 2002, nine treatment facilities for produced water from heavy oil have been set up with daily treatment of 11.9×104 m3 of produced water. With the technology, fresh water of 4343×104m3 is saved every year, saving fuel oil of 204,000t/a, recovering oil of 175,000t/a, reducing the emission of CODcr by 22,800t, resulting in direct economic benefits of 2.19 billion RMB, achieving tremendous economic, environmental and social benefits.
ExxonMobil Production Facility Integrity Management System
Authors: Killian Keith Edward , Lee Mitchell 
Published: March 2015

Abstract
The paper will provide an overview of the system developed and adopted by ExxonMobil Production Company for managing integrity and reliability of production facilities within our Operations Integrity Management Framework. The paper will cover principles, scope, key elements, processes and workflows associated with the Facility Integrity Management System (FIMS). It will also discuss critical success factors for effective implementation and lessons learned.
Safety, health and the environment are of the highest priority. Production downtime and unplanned maintenance can have significant financial and reputation impacts. Effective facility integrity and reliability management is a key element to achieving desired performance in these areas. Our structured approach to Equipment Class Program Design, Execution, Stewardship and Continuous Improvement has provided clarity on key maintenance, testing and inspection activities, and their effectiveness at achieving Program objectives. Learnings can then be incorporated back into the Program to improve effectiveness and efficiency.
The general principles outlined in this paper will provide insight on the approach to successful facility integrity and reliability management and critical success factors. The experience in developing and implementing the system will be of direct interest to professionals engaged in engineering, maintenance and operations of facilities related to oil and gas production.

Introduction

Overview
ExxonMobil remains steadfast in its commitment to excellence in Safety, Security, Health and Environmental (SSH&E) performance. In addition, high emphasis is place on production reliability and efficient, effective maintenance of our operations. ExxonMobil's Operations Integrity Management System (OIMS) is a cornerstone in managing SSH&E risk and achieving excellence in performance, and includes specific expectations for facility integrity and reliability management. ExxonMobil Production Company has addressed this aspect of OIMS through a comprehensive Facility Integrity Management System or FIMS. FIMS addresses the standards, processes, best practices and activities necessary for managing integrity and reliability of critical facilities within our production operations, and has been successfully implemented throughout ExxonMobil's operated production business globally.