bluuebunny/crossref_metadata_2025_split huggingface dataset:
Определение α- и β-нафтолов в их смесях с предварительным мицеллярно-экстракционным концентрированием
Authors: Цыгулёва Эльмира Иршатовна , Доронин Сергей Юрьевич , Рудаков Олег Борисович 
Published: April 2022

Работа посвящена раздельному и суммарному определению α- и β-нафтолов с предварительным их мицеллярно-экстракционным концентрированием неионными ПАВ и применением цифровой цветометрии. Способ определения основан на цветных реакциях α- и β-нафтолов с 4-нитро-фенилдиазонием, 4-аминоантипирином и мицеллярной экстракции продуктов их взаимодействия – азосоединений и хинониминов. Этот способ позволяет определять α- и β-нафтолы на уровне ПДК с погрешностью, не превышающей 10%. Для количественного определения нафтолов применены обобщенные цветометрические параметры в цветовой системе RGB – площадь (S) и периметр (P) лепестковых диаграмм, полученных по результатам оценки интенсивностей цветовых компонент R,G и B двух хромофорных реакций, основанных на получении окрашенных дериватов по реакции диазотирования и азосочетания, а также окислительной конденсации нафтолов. Цветометрические лепестковые диаграммы дериватов α- и β-нафтола имеют индивидуальный профиль из-за различий в их строении, что позволяет проводить идентификацию.
Для сравнения профилей лепестковых диаграмм изомерных нафтолов и их смесей применены коэффициенты близости массивов, по которым можно прогнозировать соотношение изомеров в смеси. Геометрические параметры лепестковых диаграмм индивидуальных изомеров нафтолов в полулогарифмических координатах удовлетворительно описываются линейными уравнениями S=blgC-a и P=blgC-a (степень аппроксимации R2≥0.97) и могут быть использованы для определения их концентраций в пределах 1·10-7-1·10-4 М. Для оценки правильности цветометрического определенияα-и β-нафтолов применен метод изократической обращенно-фазовой высокоэффективной жидкостной хроматографии с УФ-детектированием при 265 нм. Показано, что концентрирование дериватов α- и β-нафтолов простыми и комбинированными системами на основе неионных ПАВ позволяет раздельно определять их в диапазоне концентраций 1·10-7-1·10-6 М. Разработанный способ является экспрессным, экономически и экологически выгодным, по сравнению с методом ВЭЖХ, так как не требует применения летучих и токсичных растворителей и дорогостоящего оборудования.
Navigating Linguistic Identities: ESL Teaching Contexts in Quebec
Authors: Riches Caroline , Parks Philippa 
Published: April 2022

Linguistic identity is deeply embedded in how individuals identify within groups and cultures (Gee, 2000; Sachs, 2005). The contexts of English as a second language (ESL) teaching in Quebec and ESL teachers’ range of linguistic repertoires provide an interesting landscape for considering issues of identity, equity, and acceptance (De Costa & Norton, 2017; Norton, 2014). Through surveys, interviews and focus groups with pre- and in-service ESL teachers, we explore how language and professional identities develop through the lens of French/English identity intersections and acceptance in these teaching contexts. Our findings show a pattern that is unique to the ESL Quebec context: In French-language schools it is often how an ESL teacher’s linguistic identity is seen, rather than how they selfidentify that appears to be essential to their success in integrating into teaching communities. Our research has important implications for our understanding of the ways ESL teachers’ linguistic identities are performed and accepted within plurilingual contexts of teaching.
« En fait, je suis francophone! . . . Mais ils me voient encore comme anglophone, même si je ne le suis pas du tout. »
L’identité linguistique est profondément ancrée dans la façon dont les personnes s’identifient au sein des groupes et des cultures (Gee, 2000; Sachs, 2005). Les contextes de l’enseignement de l’anglais comme langue seconde (ALS) au Québec et l’éventail du répertoire linguistique des enseignants d’ALS fournissent un paysage intéressant pour envisager les questions d’identité, d’équité et d’acceptation (De Costa et Norton, 2017; Norton, 2014). Par l’entremise de sondages, d’entrevues et de groupes de discussion auprès des enseignants en service et des enseignants en formation d’ALS, nous explorons comment les identités langagières et professionnelles se forment par le prisme des intersections identitaires et de l’acceptation au sein de ces contextes d’enseignement. Nos résultats montrent un schéma qui est unique au contexte de l’ALS au Québec : dans les écoles francophones, il s’agit souvent de la manière dont l’identité linguistique de l’enseignant d’ALS est perçue plutôt que de la façon dont ils s’identifient qui semble être essentielle pour réussir à s’intégrer dans les communautés enseignantes. Notre recherche comporte des implications importantes pour notre compréhension des façons dont les identités linguistiques des enseignants d’ALS sont réalisées et acceptées au sein de contextes d’enseignements plurilingues.
Employed parents' reactions to work-family conflicts: Adaptive strategies of scaling back in Germany
Authors: Adams Ayhan , Golsch Katrin 
Published: April 2022

Objective: This study investigates the extent to which employed mothers and fathers scale back on working hours or job pressures in response to work-to-family conflicts (WFC).
Background: Drawing on the concept of adaptive family strategies, it is assumed that WFC is an antecedent to a reduction in work demands. Considering partners’ gender ideology net of other resources and characteristics, we can expect to see gender differences in the adoption of this strategy. Relatively little research has been conducted on associations among WFC, gender ideology, gender, and work-related coping strategies.
Method: We use six waves of the German Family Panel (pairfam, release 11.0), covering the survey years 2012-2019, to examine the effect of WFC and gender ideology on employed mothers’ and fathers’ work-related coping strategies (N=791 mothers and N=1292 fathers). OLS regression is used to estimate the effect of WFC at and gender ideology on changes in job pressure and working hours between and .
Results: Parents who experience WFC are more likely to reduce their job pressure and less likely to scale back on working hours. Gender differences in the reaction between mothers and fathers on WFC only occur in connection with traditional gender ideology.
Conclusion: Scaling back seems not to be a commonly used strategy to react to WFC.
Synthesis and Activity Test of 1-Allyl-3-(4-tertiary-Butylbenzoyl) Thioureaas a Candidate of an Analgesic Drug
Authors: Razak Rais , Siswandono Siswandono , Ekowati Juni 
Published: April 2022

Background: Urea derivatives showed good analgesic activity compared to diclofenac sodium. The addition of the allyl group to the thiourea and 4-tertiary-butylbenzoyl chlorideis expected to provide a better analgesic effect. Objective: The research aimed to synthesize 1-allyl-3-(4-tertiary-Butylbenzoyl) Thiourea and determine its analgesic activity in mice (Mus musculus). Methods: The synthesis was carried out by a modified Schotten-Baumann reaction, via nucleophilic substitution reaction of allylthiourea on 4-tertiary-butylbenzoyl chloride. A writhing test was performed to observe analgesic activity in the test compound. Confirmation of the structure of pure 1-allyl-3-(4-tertiary-Butylbenzoyl) Thiourea was obtained through UV, IR, 1H-NMR, and 13C-NMR data. Results: The compound showed better pain inhibition activity compared to diclofenac sodium, with ED5019,018 mg/kg BW. Conclusion: The compound 1-allyl-3-(4-tertiary-butylbenzoyl) thiourea showed better analgesic activity than diclofenac sodium.
Calcium Decay Ability of Extracts Chromolaena odorata L. Leaves (Asteraceae) on Kidney Stones
Authors: Indriatmoko Dimas Danang , Maulani Maulani , Rudiana Tarso 
Published: April 2022

Background: Kidney stones are one of the causes of chronic and acute kidney failure symptoms. The flavonoid compounds in Chromolaena odorata leave extract are thought to dissolve calcium in kidney stones. Objective: This study aims to determine the activity of Chromolaena odorata leaves extract as a laxative for calcium kidney stones and to characterize the active extract with a liquid chromatograph mass spectrometry. Methods: The leaves of Chromolaena odorata were extracted by ultrasonication method using 3 solvents in stages, namely n-hexane, ethyl acetate, and methanol. The powder for kidney stones was immersed in an extract solution of n-hexane, ethyl acetate, and methanol for 5 hours at 37° C. The reaction results were analyzed for their absorbance using a UV-Vis spectrophotometer. The fraction with the best activity was analyzed for phytochemical content with various typical reagents and LCMS. Results: Methanol extract of Chromolaena odorata has a better effect in dissolving calcium kidney stones. Methanol extract of Chromolaena odorata can reduce calcium in kidney stones with an EC50 value of 16801 µg/mL. Based on phytochemical tests and LCMS analysis, the methanol extract of Chromolaena odorata leaves contains compounds of the tannins, alkaloids, flavonoids, and steroids. Chromatogram at a retention time of 7.76; 8.96; and 10.01 in the methanol extract of Chromolaena odorata identified 3,5,7,4'-tetrahydroxy-8,3'-dimethoxyflavone; 5,7,4’-trihydroxy-3’,5’-dimethoxyflavone, and 5,6,7,8,4'-pentamethoxyflavone compounds. Conclusion: Methanol extract had the best calcium decay activity in kidney stones with an EC50 value of 16801 µg/mL. 3,5,7,4'-tetrahydroxy-8,3'-dimethoxyflavone; 5,7,4’-trihydroxy-3’,5’-dimethoxyflavone, and 5,6,7,8,4'-pentamethoxyflavone compounds are contained in methanol extract which is thought to play a role in shedding calcium in kidney stones.
Data Mining of In-Situ Stress Database Towards Development of Regional and Global Stress Trends and Pore Pressure Relationships
Authors: Thompson Nicholas , Andrews Jamie Stuart , Reitan Håvard , Teixeira Rodrigues Nuno Eládio 
Published: April 2022

Abstract
The in-situ stress, and in particular the minimum principal stress, is a major controlling parameter for many subsurface engineering issues, such as safe injection and injection pressure limitation, wellbore stability, fractured injection and stimulation, and completions optimization. In addition to these more ‘traditional’ field development decisions, in-situ stress has direct influence on the rapidly growing CCS industry, where storage volumes of CO2 are highly dependent on the initial minimum effective stress margins available in the sealing caprock(among other factors). In this work we investigate a unique in-house stress database, obtained through decades of dedicated stress testing, to better understand and quantify the relationship of in-situ stress versus depth and its relation to pore pressure. Focus is primarily on the Norwegian Continental Shelf but global results from additional passive continental margin areas are also incorporated and compared. We find that, almost regardless of the geographic area, when hydrostatic pore pressure conditionsapply, relatively simple linear relationships exist of stress versus depth and that the assumption of normally-stressed/relaxed stress regimes can be applied with a good degree of certainty. Further, where overpressure conditions are present, relationships dependent on the degree of overpressure are defined, both regionally and globally. The resulting overpressure relationship is found todiffer fromthose commonlyaccepted andused throughout industry, e.g. Breckels and van Eekelen 1982. Finally, the resulting stress trends versus depth are investigated to better identify the potential presence of high stress environments such as deeper strike-slip to reverse faulting regimes that can complicate field development decisions. While of interest to the hydrocarbon industry in general, the results of this work are highly valuable to under-explored areas where in-situ stress data is not yet available, e.g. saline aquifer prospects targeted for eventual CCS development.
Design, Optimization, and Visualization of Wellbore Trajectory in 3D
Authors: Sahebi Hamed , Wiktorski Ekaterina , Sui Dan 
Published: April 2022

Abstract
Well planning and well trajectory design in particular is a complex iterative process, which typically takes several months and significant effort from drilling engineers and other field professionals. When several wells are drilled from the same platform or subsea template, tubular program, cement program, and mud program are rather consistent from one well to another. The biggest challenge lies in wellbore design, which should allow fast, cost-efficient, and problem-free drilling and subsequent casing- and lower completion running.
This paper presents 3D wellbore trajectory design and visualization modules within an in-house well planning web software developed at the University of Stavanger. The design and optimization module allows users to construct 3D wellbore trajectories using Bezier curves and optimize them with respect to the geomechanical and hydraulic characteristics using a principle of hydraulic mechanical specific energy (HMSE) and minimum drilling time. Other optimization criteria have been already developed separately from the simulator and will be included in the later release.
The visualization module provides a 3D picture of the well under construction with respect to the offset wells, statistics visualization and data filtering of the drilled wellbore sections to determine, for instance, high ROP and low tortuosity areas. Volve data set, released by Equinor in 2018, was used for the development and testing of the modules.
It is evident that the current well design methodology has a real potential for improvement. The application of the newly developed well planning and visualization tool will reduce time the iterative process takes, from hours and days to just several minutes. The advanced visualization tool will aid wellbore construction by providing well planners and drilling engineers with information about possible problem areas and opportunities during drilling. The new approach to wellbore trajectory design will make the well planning more interactive, robust and time-effective.
Energy Efficient Operation of Petroleum Production Plants
Authors: Holt Torleif , Schümann Heiner 
Published: April 2022

Abstract
The use of energy and the possibilities for energy recovery from pressurised fluid streams has been analysed for a petroleum production plant connected to an undersaturated oil field that was produced by water injection. The plateau production of oil was 15900 Sm3/d and water was injected at a rate of 20670 m3/d. The produced fluids arrived at the production plant at a relatively high pressure and temperature (70 bar and 82 °C). Produced oil and gas were continuously exported from the plant at 200 bara.
The power consumption in the plant could be reduced by using equipment with high efficiency. The average power over the 27-year lifetime of the field was reduced from 19.95 MW to 14.78 MW for two scenarios using different equipment. This corresponds to a reduced energy consumption and reduced CO2 emissions of 986 million kWh and 692502 tonnes, respectively. Energy can be recovered from pressurized process streams. For the hydrocarbon streams in the plant turbogenerators were considered. Pressure from produced water could be recovered by use of pressure exchangers. On average 2 MW power was recovered over the lifetime of the field, saving 486 million kWh electric energy corresponding to 341166 tonnes CO2 emissions. All energy savings above apply both to plants powered by gas turbines and electrified fields.
CO2 emissions per unit of potential combustion energy from produced petroleum was very low in the plateau phase of the production. Only late in the lifetime of the field the emissions approached and exceeded (depending on scenario) the average emissions of 5 g CO2/MJ for fields on the Norwegian Continental Shelf.
The high potential for reduced energy consumption in the petroleum production plant and for energy recovery was due to the relatively high inlet pressures to the plant and high pressures of injected water. For lower inlet pressures and better water injectivity the potential will be lower, and fields should be studied case by case. Factors such as weight and space requirements of new alternative process equipment, cost and maintenance have not been considered in this work.
In an electrified field the abundant supply of thermal energy from gas turbine exhaust will not be available. Thermal energy was available from the produced fluids and from the petroleum processing and could be sufficient e.g. for heating of housing areas and heating of process streams. If higher temperatures were needed heat pumps can be taken into use. Dedicated and field specific studies regarding use and recovery of thermal energy and possible applications of heat pumps must be done to find optimal solutions for the thermal energy demand of an electrified field, however.
Integration of Johan Sverdrup PRM 4D Data Into the Dynamic Model
Authors: Calvert Monica Anne , Tsaplin Yuri , Hansen Hans Peder 
Published: April 2022

Abstract
The Johan Sverdrup field PRM (permanent reservoir monitoring) system has now recorded 2 monitor surveys documenting the progression of the water flood since production and injection began in October 2019 revealing a clear 4D signal linked to the increase in water saturation.
The PRM system was installed in two stages in 2019 and 2020 and is a key component of the reservoir monitoring and data acquisition plan with yearly monitor surveys planned to monitor the water flood development. The first seismic acquisition in 2019, referred to as PRM0, covered the initial first stage of installation on the northern part of the field. Stage two of the installation was completed in 2020 and two monitor surveys have since been acquired covering the entire field, in 2020 (PRM1) and 2021 (PRM2). Clear 4D signals can be seen due to the increase in water saturation and show the waterfront moving updip as it pushes the oil towards the producers.
The Johan Sverdrup field consists primarily of the intra-Draupne sandstone and the secondary Statfjord sandstone reservoirs. The intra-Draupne sandstone has excellent reservoir quality with an average porosity of 28% and permeabilities ranging from 30-70D. The Statfjord sandstone has an average porosity and permeability of 24% and 4D, respectively. The reservoir is undersaturated and has good lateral and vertical communication. These properties lead to a measurable 4D response when water replaces oil as the water flood progresses through the reservoir.
The 4D data is an integral part of the reservoir management program, and together with the geological and production history data, is being used to update the reservoir model to further our understanding of the field development. Examples of the 4D acoustic impedance change generated via a proprietary geostatistical inversion and how it is integrated into the dynamic model will be shown.
Streamlining Oil and Gas Operations Using Data-Driven Solids Management Services
Authors: Nilsson Olof , Skåland Aksel , Arefjord Anders , Greenland Steve 
Published: April 2022

Abstract
With approximately 70% of the world's petroleum located in poorly consolidated reservoirs, sand production is a global challenge. This paper explains a new well testing concept to optimise and maximise the production potential. This is achieved by finding the limit of topside sand production when the sand comes from the reservoir or is accumulated in the wellbore. If the sand comes from accumulation in the wellbore, it is removed by a cleanout operation (bottom-up) and measured by weight until the well stabilises on lower sand production to be confirmed coming from the reservoir. The next step will be to adjust the well flow to the acceptable sand rate (ASR) while still flowing at a rate not to accumulate sand in wellbore. This is difficult to achieve without proper sand measurement tools. A patent-pending well- testing method has been developed using Dual vessel desander solids management systems with regular well testing information. This method provides a complete picture of the sand production at the same time as the production potential of the well is discovered and realised. This is done while simultaneously reducing the effects of erosion from solids and without sand being transported to downstream process facilities.
A dual vessel desander unit is installed during well testing to ensure sand protection for the downstream process facility. The system combines several data elements to measure solids production in real-time. The real-time data enables operators to tune wells individually for increased oil and gas production (Typically above the ASR production flow level). At the same time, ensuring produced solids are removed, measured and handled upstream of the process facility.
The method shows several benefits; including improved guidelines for a well start-up (also often referred to as a well bean-up) to avoid sand to the surface, identifying unrealised production potential while maintaining solids below the ASR, and lowering overall sand production that enters the production separator by regularly cleaning wells with dual vessel desander systems.
A case study from the North Sea is shared. An Operator utilised the method to reduce their coiled tubing cleanout operations due to continuous surveillance of sand producing wells that were brought into clean-up mode via the desander before they lost too much pressure and ceased production. ESG improvement over eight years, as the operator eliminated 20 coiled tubing clean-out operations, reducing operations cost, risks of heavy lifts, personnel mobilisations, and emissions per barrel produced.
Water Shutoff Technologies for Reduced Energy Consumption
Authors: Bergmo Per Eirik Strand , Grimstad Alv-Arne 
Published: April 2022

Abstract
Oil and gas operators on the Norwegian Continental Shelf (NCS) are working to reach goals of reduced CO2 emissions associated with production of hydrocarbons. Emissions from offshore operations mainly comes from generation of power required for processing and drainage of the oil and gas fields. Therefore, one option for reducing emissions is to reduce the energy consumption associated with water injection and production. Inflow control devices and smart wells have traditionally been used to increase oil production. They can also have benefits like reducing need for lifting produced water to platform and reducing volume of injected water necessary to maintain production.
The LowEmission Centre (LowEmission) is an eight-year research program managed by SINTEF that aims to develop technologies and solutions for reduced offshore greenhouse gas emissions on the NCS in line with the emission goals of the government and the petroleum industry. This paper presents work performed in the centre on modelling and simulating the effect of autonomous inflow control devices on oil and water production profiles and on energy use for water injection. The largest potential for this technology seems to be for long horizontal wells with autonomous devices that can discriminate between and constrain selected phases flowing into the well. The specific inflow technology investigated can discriminate between phases based on their (reservoir) densities.
Reducing water production will reduce the need for lift in wells with high water production. It is demonstrated that a reduction in water production will also reduce the need for water injection, giving opportunities for reduced energy use in the drainage process. Restricting water production can also give a reduced oil production rate, however this reduction is modest compared to the reduction in water production.