bluuebunny/crossref_metadata_2025_split huggingface dataset:
Efectividad de una estrategia educativa en la prescripción de la tromboprofilaxis adecuada en un servicio de Medicina Interna de un hospital general
Authors: Vásquez Kunze Sergio , Sosa Valle Hector , Leiva Reyes Natalí , Loza Munarriz César , Pulcha Guerra Alejandro , Villaverde Peláez Homarh 
Published: March 2024

Objetivo: Determinar el impacto de una intervención educativa sobre la frecuencia de prescripciones médicas adecuadas de tromboprofilaxis en un servicio de medicina de un hospital general. Material y métodos: Estudio quasi experimental, en el cual en la fase pre-intervención se obtuvieron las frecuencias de indicación de tromboprofilaxis adecuada por parte de los médicos del servicio de medicina. Se realizó una intervención educativa de 8 semanas a este mismo grupo de médicos. En la fase post intervención se midió la frecuencia de la tromboprofilaxis adecuada a los 2 y 4 meses después de la intervención. Resultados: La intervención educativa se implementó en 112 médicos residentes de las especialidades de medicina. La totalidad de prescripciones fueron hechas por los médicos residentes de primer año y refrendadas por su médico supervisor. Previamente a la intervención se obtuvieron 47 (44,35%) prescripciones adecuadas, 13 (12,26%) subóptimas, 4 (3,77%) inadecuadas y 42 (39, 62%) ausencia de prescripción. Luego de la intervención se obtuvieron a los 2 meses subsiguientes: 78 (75,72%) prescripciones adecuadas, 7 (6,79%) subóptimas, 4 (2,91%) inadecuadas y 15 (14,58%) ausencias de prescripción, habiendo diferencia significativa con el nivel basal. A los 4 meses subsiguientes postintervención se obtuvieron: 86 (83,49%) adecuada, 5(4,85%) subóptima, 2 (1,94%) inadecuada y 10 (9,72%) ausencia de prescripción, habiendo diferencia significativa con el nivel basal. No hubo aumento en la frecuencia de sobre uso. Conclusiones: La aplicación de una estrategia educativa al personal médico fue efectiva en el incremento de las prescripciones de tromboprofilaxis correctamente indicadas en un servicio de medicina. No se encontró sobreuso de la tromboprofilaxis luego de la intervención.
Excess Mortality Calculations to Assess the Impact of the COVID-19 Pandemic: Concepts and Methodological Issues
Authors: Vandenbroucke Jan P. , Pearce Neil 
Published: March 2024

We discuss some intriguing methodological aspects of excess mortality analyses, which have been widely used to describe the impact of the COVID-19 pandemic. We describe the main ways of presenting excess mortality: as a mortality rate (incidence rate) or as a percentage increase (relative risk or rate ratio). We discuss what should be regarded as the null value of excess mortality (i.e., when countries or regions can be judged as having fared equally well) and when age and sex standardization, adjustment for other determinants of the spread of a pandemic, or both is necessary. We discuss the level of detail by time and place and person that may be necessary. We note that an excess mortality comparison is essentially a difference-in-differences analysis. We conclude that, although one cannot rule out using excess mortality analyses for causal effect estimates, such analyses will remain most fruitful for generating hypotheses about both the efficiency of measures to curtail the pandemic and factors that cannot be influenced. Nevertheless, a judicious use of arguments and counterarguments can then lead to identifying best practices for various situations. ( Am J Public Health. 2024;114(6):593–598. https://doi.org/10.2105/AJPH.2024.307572 )
Produced Water Treatment and Reuse Options: Alternatives for Sustainable Water Resources
Authors: Dawoud Mohamed A. , Sefelnasr Ahmed , Ebraheem Abdel Azim , Alnaimat Fadi , Mathew Bobby , Hamouda Mohamed A. , Hassan Ashraf Aly , Zubari Waleed Khalil , Sherif Mohsen 
Published: March 2024

Abstract
Water conservation and sustainability are of utmost importance in the Abu Dhabi Emirate, and they are considered key areas of strategic significance for the United Arab Emirates. The escalating demand for freshwater resources, coupled with the absence of a proportional rise in surface and groundwater supplies, necessitates the exploration of other water sources. Among these potential alternatives, produced water (PW) holds significant promise. Nevertheless, there is a lack of comprehensive characterization of the amounts of the generated produced water, as well as the quality and management of such water in the Abu Dhabi Emirate. The primary aim of this research was to study the amount and quality of produced water (PW) connected with the oil and gas sector, with the goal of evaluating its potential contribution to the water budget of Abu Dhabi Emirate. PW refers to the water that is naturally occurring in subsurface formations and is extracted to the surface during oil or gas production operations. The composition of the fluid may include water sourced from the reservoir, water that has been previously injected into the formation, and any chemical substances that have been incorporated throughout the various stages of production. The majority of PW has a significantly high salinity level and may consist of a combination of mineral salts, organic compounds, hydrocarbons, organic acids, waxes, and oils. Additionally, it may include inorganic metals, other inorganic components, naturally occurring radioactive material, chemical additives, as well as other constituents and byproducts. A comprehensive investigation was conducted to explore a multitude of viable management methods and treatment technologies aimed at mitigating salinity, which is recognized as a significant constraint in the usage of produced water. Furthermore, an examination was conducted on the origins, features, and magnitude of several contaminants present in the PW. In addition to total volumes produced, the water-to-oil ratio (WOR) from production activities was considered as this information can be used to evaluate the relative production age of resources within the production lifetime. On a global scale, the average PW production is around 280 million barrels per day, in contrast to the production of oil which stands at roughly 97 million barrels per day. This research included an update to the worldwide water-oil ratio (WOR) to a value of 4:1, indicating a water reduction of around 75%. The WOR ratio in the Gulf Cooperation Council countries has considerable heterogeneity, with an average value of 7:1. In this regard, it should be noted that the highest PW contributors are not always the most prolific producers of oil and gas.
Optimizing Sustainable Polysaccharide-Based Drilling Muds with Red Mud for Geothermal Applications
Authors: Ba Saloom Salem , Ba Geri Mohammed , Suhail Mohamed 
Published: March 2024

Abstract
Geothermal drilling demands specialized drilling fluids to handle extreme high temperature high pressure (HTHP) environments. Conventional water-based muds (WBMs) utilize mined minerals like bentonite with toxic polymers, causing environmental harm. Produced water (PW) is an abundant byproduct of oil/gas production posing disposal issues. Red mud (RM) is an alkaline waste from aluminum refining that is landfilled. This research investigates formulating sustainable PW-based muds (PWBMs) with RM for geothermal drilling. RM was characterized and hot-rolled PWBMs were optimized evaluating rheology, fluid loss, and solids suspension capacity at HTHP conditions.
PW displayed high salinity up to 224,937 ppm and hardness up to 15,932 ppm, presenting technical barriers including clay swelling, scale potential, and incompatible fluid chemistry. However, engineered PWBM formulations resolved these issues. Increasing polysaccharide concentrations enhanced yield point, gel strength, and low-shear rate viscosity of PWBMs. At 8 ppg polysaccharide dose, saline PWBMs achieved viscosity surpassing freshwater WBMs. RM inclusion further reduced fluid loss by 50% versus conventional calcite mud system (CCMS). PWBMs also demonstrated superior sag resistance, with 8 ppg polysaccharide enabling sag factors as low as 0.5-0.53 in vertical and inclined orientations.
This pioneering research successfully developed sustainable PWBMs leveraging two waste streams. RM improved filtration control as a benign substitute for lignosulfonates. Demonstrated technical performance resolves produced water reuse limitations in geothermal drilling. Optimized PWBMs met drilling fluid specifications while utilizing only non-potable resources. This eliminates sourcing, water, energy for conventional WBM components with associated environmental and economic savings. Integrating green design principals, this study provides a sustainable technology pathway significantly reducing impacts for geothermal well construction. Field validation is recommended to facilitate commercial adoption.
Overall, red mud is a promising new option for geothermal drilling fluid additives. It is more environmentally friendly, and it can improve the performance of drilling fluids under HPHT conditions. The possibility does exist for the red mud additive to be used as an inert additive to optimize various drilling fluid properties.
Integrating Water Management Life Cycle Assessment in Upstream Oil and Gas: A Pathway to Enhanced Waterflood
Authors: Maire F. , Alblooshi J. R. , Ali A. E. , Littler D. , De Plaa P. J. C. 
Published: March 2024

AbstractThe urgency of optimizing water management in the oil and gas industry has never been more pronounced, as mega reservoirs and basins approach later life, especially against the backdrop of intensifying environmental regulations and the global push for sustainable practices. As conventional onshore and offshore oil developments mature, particularly in the context of the Middle East's carbonate reservoirs, the need for efficient, cost-effective, and environmentally responsible water management strategies becomes paramount. This paper presents a comprehensive study aimed at integrating Water Management Life Cycle Assessment (WMLCA) in the context of Upstream activities.The study focuses on Produced Water Handling (PWH) and Water Injection (WI) systems. The model is built upon a bottom-up assessment of water-related costs and is positioned as a strategic tool for high-level cost / emission estimation and planning. By focusing on the conventional oil fields of the Middle East, the study steers clear of more complex scenarios such as Enhanced Oil Recovery (EOR) and deep offshore developments, thus providing a clear, focused analysis relevant to the region's predominant operations. A critical component of this study is its alignment with ADNOC's net-zero ambitions and its broader Waterflood Excellence framework. The increasing relative volumes of produced water (PW) and water injection (WI), coupled with the imperative for emission reduction, present both challenges and opportunities. This study not only scrutinizes these aspects but also offers strategies to optimize waterflood processes, enhance water quality management, develop technologies, and contribute to ADNOC's sustainability goals.This paper explains how the complete WMLCA model was created, developed, and used. It shows the method, data, and the advanced analytics we used to make this happen. The paper wants to help industry professionals and stakeholders understand, plan, and use tools for water management in oil and gas operations.
Rig Less Solution for Permanent Isolation of Unwanted Water Production Zone in an Oil Well to Sustain the Oil Production and Reduce the Water Production and Treatment Cost
Authors: Douik H. , Rachapudi R. , Negi Rohit S , Abaza Fayez , Ubedulla Shaik Saheb 
Published: March 2024

Abstract
This paper describes the systematic approach towards nullifying the water production from the oilwell by setting an inflatable and pumping water shut off solution beneath. An onshore oil producing well in the United Arab Emirates was producing high water-cut impacting overall oil production and increasing water production and treatment requirements. The objective of the well is to improve oil production and reduce water production. Well data was reviewed systematically including completion limitations, deviation survey, sour conditions along with recently carried out production logging information. The production logs identified that the lowermost zone is producing most of the water and needed to be shut off.
The solution was designed with an inflatable retainer system having 2.125″ outer diameter and customized water shut off solution. The pressure differential capacity of this inflatable packer was evaluated using a software simulation and chemical water shut-off solution was designed within the limitation inflatable packer minimum differential capability. Proper lab testing of the Chemicals was carried out to finalize the setting time. The volume of chemical was finalized based on geological features and shut-off intervals. In summary a Coil tubing Conveyed solution was finalized after screening other possible bull head options.
The solution was implemented at the candidate well after overcoming the operational challenges, completion restrictions and resources limitations. The paper highlights the candidate evaluation, solution screening, lab testing, execution challenges and successful results. In summary the solution reduced more than 700 BWPD of water production that resulted in saving treatment cost, water handling capability limitation and power optimization in producing the well using ESP system. This rig less solution provided an economic alternative for avoiding unwanted water while enhancing oil production capacities that resulted in increasing well life and profitability.
This new approach of setting an inflatable cement retainer and pump the water shut off solution in rig less environment at wells having tubing restrictions provides an alternative solution that avoids the requirement of workover rigs and minimum timeframe to put back well on production.
Nano Chemical Technology to Reduce Produced Water from Oil Wells
Authors: Dhafeeri Abdullah , Almusabeh Muzher , Bukhari Syed Muzafar Ali 
Published: March 2024

Abstract
The excess of water production from oil and gas wells in several areas of the oil field is a subject of concern for reservoir management. A conformance chemical treatment can be used to improve the production profile of a well and minimize unwanted water. Unwanted water production causes major economic, operational, and environmental problems during oilfield operations. First time, Nano chemicals are implemented as a safe and unique system with a great deal of benefit in terms of well productivity enhancement taking into consideration the most challenging limestone carbonate reservoir characteristics such as tight permeability. In addition, selection well candidates from Middle East oil fields were made to treat subject oil wells that encountered high water cuts. The designed nano chemical is to be more reliable and new advanced technology to reduce produced water in oil wells. Nano chemicals have no negative impact on artificial lift systems such as ESP equipment. The nano chemical is biochemical and friendly environmental handling. Chemistry solutions are required to remove the negative impacts of high-water cut on oil wells through well treatments by reducing/minimizing the produced water from a reservoir. That water contains natural salts and organic compounds with injected chemicals that need pre-treatment up to the permissible limit of environmental legislation at onshore environments. Smart nanotechnology with biosurfactants demonstrated high thermal stability and affinity to meet the technical challenges of reservoir conditions, element environmental crises, and improve deep reservoir penetration. The first time Smart nano-based particles are combined with biochemical to develop stronger and more durable formulations for water applications in the oil and gas industry and has been implemented in the Middle East successfully. This paper explores chemical water shutoff techniques, and well stimulation technologies to lower unwanted water production, improve sweep efficiency, and reduce the environmental impact. The wells criteria selection for field trial is based on treating the most difficult and challenging wells with serious issues related to productivity decline, and high water cut. Several previous chemical treatment attempts were conducted with a low rate of success. The field cases showed a high rate of success and an increase in the productivity rate of treated oil wells with a reduction in produced water.
Sustainable Approach of Turning Oily Produced Water into Slickwater for Unconventional Reservoir Development
Authors: Xu L. M. , Qi Z. Y. , Huang T. P. , Kalgaonkar R. 
Published: March 2024

Abstract
Produced water (PW) is generated in a large amount worldwide and has complex compositions. PW treatment is required to meet environmental regulations as well as reuse and recycling of PW. Meanwhile, plenty of water is needed for slickwater fracturing applications during unconventional reservoir development. This study aims to find effective ways to treat PW and formulate it into slickwater for fracturing operations to save fresh water and improve water sustainability. A synthetic high salinity oily produced water with overall salinity of more than 100,000 ppm was used. Searching effective chemicals and optimizing their dosages for PW treatment were based on measurements of oil-water separation time, floc volume and transmission intensity using stability analyzer which allows a step-by-step vertical scanning of dispersions. After treatment, PW was used to prepare slickwater. Hydration time and viscosity of selected dry friction reducer (DFR) in the PW were measured by rheometer, and friction reduction performance of the slickwater was evaluated by a standard friction flow loop system. The developed chemicals are efficient and economical for the PW treatment with short oil-water separation time, high oil removal efficiency, and low chemical dosage. Floc formed quickly and separated from the water phase in several minutes after chemical addition and clear bottom phase was observed. The oil content was reduced to less than 20ppm and total suspended solid was reduced by 80% within 10 minutes with the addition of 30ppm chemical. DFRs for unconventional reservoir development are selected in this work because of simple logistic handling under harsh environmental conditions comparing to liquid and emulsified friction reducers. An optimized DFR formulation which was compatible with treated PW was developed. The DFR was able to totally dissolve in PW in 1 minute. The viscosity of DFR in treated PW at different temperatures was almost same as that of solution prepared using synthetic brine. The friction reduction can reach up to 75% in less than 2 minutes. This indicates that the PW after treatment is applicable for either re-injection or reuse as base water for slickwater fracturing. This work provides the insight of oily produced water treatment by chemical method for slickwater fracturing. This significantly alleviates oilfield produced water discharge and improves water sustainability by saving large volume of fresh water for unconventional reservoir development.
Flowback Emulsions Issues for Complex Crude Oil Fluid-Phases Separation Testing and Manage by Demulsification or Water Clarification
Authors: Franca L. M. , Kotisso Y. 
Published: March 2024

Abstract
Drilling and completion of new or mature wells are a conventional method for companies to avoid standard oil production decline. Many of these wells are drilled in existing fields to produce from zones that are considered economical. Companies initially produce fluids into a frac tank to prevent production fluids contaminated with drilling mud or completion fluids from flowing to the production facilities. However, most wells still contain enough contaminants that cause drilling fluid induced emulsions during initial production to the plant such as chemical polymers, acids, surfactants, foamer agents, and others.
Some purposes of a drilling fluid or completion jobs and work over programs are to provide hydrostatic pressure to prevent formation fluids from entering the wellbore, carry the cuttings to the surface, minimize formation damage, and lubricate the drilling string and bit. Multiple chemicals and other compounds are combined to provide these functions. Traces of the filter cake and other skin damage remain in the near wellbore after the well is completed. These contaminants provide concern as they have potential to produce challenging drilling fluid induced emulsions in the production systems.
Several types of drilling fluids were identified as potential candidates for drilling the new wells on this work. The several candidates consisted of water-based, brine-based, oil-based, and synthetic-based drilling muds. Multiple tests were completed to simulate the effects of the drilling mud on the production system. These fluids were added in iterations of less than one percent based on total production. Each drilling fluid iteration was treated with varying fluid separation chemicals, applying different dosages and strategies. The fluids separation test provides the least impactful drilling fluid on the production fluids. The test also highlights the optimal fluids separation chemistry to treat the new wells.
This paper summarizes the best practice to identify the optimal drilling fluid and fluid separation chemistry via fluids separation testing. The paper discusses the crude oil characteristics and briefly describes the production system to provide the reader insight on the key areas when drilling induced emulsions create challenges with incumbent treatment programs.
Application of Autonomous Inflow Control Valve (AICV) Technology to Enhance Oil Production and Reduce Unwanted Water Production: Case Studies
Authors: Kherroubi D. , Cristea Z. , Alshehhi S. Saeed , Douik H. Mohammed , Celma R. , Alawadhi O. Abdulaziz , Albarracin R. 
Published: March 2024

Abstract
Managing water production in fractured carbonate reservoirs is a big challenge due to the uncertainties surrounding conductivity and the fracture matrix. Early water breakthrough from fractures due to the contrast in fluids mobility, particularly in horizontal barefoot completion wells, can lead to shut-in wells and by-passed oil, which cannot be produced without modifying the well design. Subsurface Technologies such as inflow control completions capable of stopping highly mobile water producing from fractures and stimulating by-passed oil to flow would be needed.
This paper describes a successful pilot application of the Autonomous Inflow Control Valve (AICV) completion in horizontal wells producing dead oil from two carbonate fields in UAE. It summarizes the technical learnings, the deployment strategy and the design philosophy followed.
The technology in principle can identify fluid flowing through it and restrict the high water or gas saturated zones autonomously while stimulating oil production from healthy oil-saturated zones.
The Autonomous Control valves can differentiate the fluid flowing through it via fluid properties such as viscosity and density at reservoir conditions, with a design based on Hagen-Poiseuille and Bernoulli's principles. Based on the Integrated performance reviews, the technology has shown the benefit of accelerating oil production as well as reduction of unwanted water which not only reduces the OPEX of these wells but at the same time has a positive impact on the environment and Green House Gases (GHG) emissions.
The delivered results supported the adoption of the technology on similar conditions and challenges. The provided solution effectiveness is continuously monitored to improve Lower completion design and increase production uptime.