bluuebunny/crossref_metadata_2025_split huggingface dataset:
İznik Meslek Yüksekokulu Turist Rehberliği Bölümü Öğrencilerinin COVID-19 Nedeni ile Uzaktan Yapılan Eğitime Bakış Açıları
Authors: ACUN KÖKSALANLAR Ayşen , ESENKAL ÇÖZELİ Füsun 
Published: November 2021

Amaç: Bu çalışmanın amacı İznik meslek yüksekokulu turist rehberliği bölümünde öğrenim gören öğrencilerin uzaktan eğitime yönelik bakış açılarının belirlenmesidir.
Tasarım/Yöntem: Saha araştırmasında yöntem olarak yarı yapılandırılmış mülakat tekniği ve tesadüfi olmayan örneklem yöntemi kullanılmıştır. Görüşmeler sonrası formlardan elde edilen veriler içerik analizine tabi tutulmuştur.
Bulgular: Yapılan içerik analizi sonucunda öğrencilerin %52’sinin uzaktan eğitimi olumsuz olarak değerlendirdikleri belirlenmiştir. Öğrencilerin, birebir eğitim ve sınıf ortamının olmaması, iletişim kurulamaması, internet sorunları, bilgisayar gibi teknik araç eksikliği gibi nedenlerle uzaktan eğitimi olumsuz olarak değerlendirdikleri belirlenmiştir. Turist rehberliği öğrencilerinin ders çalışmaya isteksiz oldukları, odaklanamadıkları, derslerden ve okuldan uzaklaştıkları da çalışma sonucunda tespit edilmiştir. Öğrencilerin %6’sı rahat ve konforlu bir ortam olması, kolay, ulaşılabilir ve zamanın etkin kullanılması gibi nedenlerden dolayı uzaktan eğitimi olumlu olarak değerlendirmişlerdir.
Sınırlılıklar: Örneklemin sadece İznik MYO turist rehberliği öğrencilerinden oluşması ve pandemi nedeniyle saha araştırmasının online yapılması araştırmanın sınırlılığıdır.
Özgünlük/Değer: Çalışma COVID-19 Pandemi sürecinde, uzaktan eğitimde yaşanan fırsat ve sıkıntıların neler olduğunun saptanması ve bu yönde gerekli olan çalışmaların yapılması açısından önem arz etmektedir. Yapılan yazın taramasında bu doğrultuda yapılan kısıtlı çalışmaya rastlanmıştır.
Minimization of Negative Impact of Well Cementing on Productive Horizons by Utilization of Swellable Packers
Authors: Paduchak Mykhaylo , Dudzych Viktor , Boiko Anatolii 
Published: November 2021

Abstract
Avoiding of negative impact of slurry contact with productive sections by utilization of swellable pakers well completion systems as a key solution for depleted reservoirs. Results are compared to previously used classic well completion method with production casing cementing
The new method of the well completion is based on a long period and many wells operations within Svyrydivske field in Dnipro-Donets Basin (here and after DDB). Precise selection of hybrid, oil and water based elastomers and correct placement in the appropriate hole zones for water and sectional isolation together with oil based mud utilization during drilling have provided stable production in depleted reservoirs and have minimized negative consequences from water filtration. The results achieved and the well completion method are described in detail to allow readers to replicate all results in a comparable geological conditions in DDB.
Current well completion method has a couple of outstanding results achieved:
– well integrity barrier is based on sufficient differential pressure provided by swellable packers; – reliable long term water isolation of all detected water contained intervals; – the production sections are not polluted by slurry filtrated water; – increased production rate comparing to cemented wells; – no risks of slurry loss during well cementing.
This technology has been successfully implemented in both vertical and deviated wells on 4.5″ (114.3 mm) casing OD, in the interval 5100-5450 meters, bottom hole temperature 120-135°C. The differential pressure provided by swellable packer is up to 10,000 PSI (68.9 MPa). Fluid reactive packers are ready to expand and isolate highly cavernous hole sections and keep differential pressure sustainably. To achieve the best results with this well completion method, it is also important to use reliable gas tight casing connections and know precise reservoir characteristics. That is why the technology is recommended to be customized for well known brownfield reservoirs with high rate of depletion.
The main benefit of the well completion method is a proved and safe technical solution for mainly depleted deep gas and condensate deposits in DDB (Ukraine) with sensitive economics
Theoretical and Methodological Features for Gas-condensate PVT Fluid Modelling with Limited Data
Authors: Burachok Oleksandr , Pershyn Dmytro , Kondrat Oleksandr , Matkivskyi Serhii , Bikman Yefim 
Published: November 2021

AbstractMajority of gas-condensate reservoir discoveries in Dnieper-Donets Basin (Ukraine), is characterized by limited composition only up to C5+, phase behavior studied by non-equilibrium, so called differential condensation PVT experiment, combined with the uncertainty in condensate production allocation to individual wells, makes the direct application of the results in modern PVT modeling software not possible. The new method, based on the Engler distillation test (ASTM86) for definition of pseudo-components combined with synthetic creation of liquid saturation curve for CVD experiment, was proposed and successfully applied for different gas-condensate reservoirs in the area of study. The quality control (QC) of the PVT model is further performed by applying material-balance method on a single-cell simulation model for exported black-oil PVT formulation when needed.The method proved being useful for modeling of multiple gas-condensate reservoirs of Dnieper-Donets Basin with different potential condensate yields varying from 30 to 700 g/m3 and as an example presented for two reservoir fluids with 108 and 536 g/m3. Results of numerical simulation studies were within the engineering accuracy in comparison to historically observed values. The investigation showed that a representative fluid model can be create in the cases when no detailed fluid composition or required laboratory experiments are available. PVT model can be efficiently validated and QC-ed by performing material-balance type numeric simulation constructed with one cell. However, the proper fluid sampling and PVT cell laboratory experiments are still major requirements for precise reservoir fluid characterization and equation of state (EOS) modeling.
Strategic Value of Basin Analysis Teams in Exploration – Applications in Ukraine
Authors: Wygrala Bjorn Peter , Karpenko Ivan , Monreal Felipe Rodriguez 
Published: November 2021

AbstractA proven approach in exploration management is to establish multi-disciplinary Basin Analysis (BA) Teams that follow industry best practices and standardized procedures to deliver geologic risk assessments to both management and asset teams. Team members have the ability to provide a combination of specific technical expertise that is used to develop long-term foundation knowledge of basins and plays, but at the same time enables them to react to management and asset team requests for rapid assessments such as block and prospect risking/ranking and investigations of specific geologic challenges.In this paper, we review requirements for the establishment of successful Basin Analysis (BA) teams and provide examples of methodologies, strategies and technical workflows that are being applied to address exploration challenges in the three main exploration target areas in Ukraine, the Western Black Sea (WBS), the Dieper-Donets Basin (DDB) and the Carpathians are in Western Ukraine. For each of these target areas, we provide an example of a BA Team strategy that is followed to address specific exploration challenges. The application of industry standard best practices in exploration by a dedicated expert team and close cooperation with asset and technical teams within the organisation ensures that these engagements will make an important contribution to improve the efficiency and success rates of exploration activities in Ukraine.
The Implementation of the Largest Geological and Production Corporate Database in Ukraine to Accelerate Digital Transformation
Authors: Reshetniak Vadym , Akono Arsene , Sherif Rana , Boumehdi Amine , Morsli Sid Ahmed , Popko Yaroslav , Yusupov Diliaver , Zharkeshov Sanzhar , Valetnyn Loktiev Valetnyn 
Published: November 2021

Abstract
Two years ago, geoscientists of the leading East European gas producers were still using paper logs, unknown data quality sources, and many data versions, stored on individual local disks for their interpretation jobs. To overcome this challenge, the deployment of a geological and production database was initiated in the framework of the digital transformation programme. The key objectives were to build a single data repository for all company assets and integrate it with the production and drilling business systems.
The development of the corporate data repository started with an extensive data assessment. A report of available data types, business processes, recommended data management, and business rules were produced. Loading and quality control procedures were designed to load over 40 different data types, including geology, geophysics, production, and drilling. Standardisation of data available in non-industry formats was necessary, e.g. for Lithology data. To enable reporting of drilling and production data stored in the business systems, complex integration and synchronisation between different Database Management Systems were developed. Data delivery to petrotechnical applications was a key to productivity.
By implementing this centralised and unique Corporate Data Storage, digitalization and loading of the well, log, seismic, drilling, and production data with proper quality were enabled. Petrotechnical experts can now use one data access point to retrieve data into their applications quickly and efficiently using just an integrated web browser. Searching information within SEGY or DLIS files was previously a difficult process that has been facilitated through an application user interface displayed in the local language. Thousands of well logs, documents, and reports have been digitised and made available in the system. The interpretation results and knowledge are now captured and reused in future field development planning. All the company data including drilling and production data synched from business systems are now available in a single place and accurate reporting can be facilitated. The system allowed the reduction of the time spent by the users searching and data quality checks.
Effective Technology to Fix Horizontal Wells with a Liner for Subsequent Development by the P&P Method
Authors: Paroshyn Dzmitry , Siarhei Leliauski , Dzianis Pilipchuk , Uladzimir Palaheyenka 
Published: November 2021

Summary
One of the priority directions of technological development of RUE "Production Association" Belorusneft "is the involvement in the development of unconventional oil reserves and enhanced oil recovery.
Achievement of this goal was hampered by such a technological challenge in the field of well construction, as providing reliable support for a well with an extended horizontal completion during development by the P&P method.
The essence of the challenge was that when performing a cluster or multi-stage hydraulic fracturing, increased loads are created on the well support, which can violate its isolation.
The complexity of the geological and technical conditions in the Pripyat trough lies in the large length of horizontal ends in salinized carbonate reservoirs and high hydraulic fracturing pressures during well development.
The article discusses solutions for the design and creation of a reliable cement sheath for the given geological and technical conditions.
To overcome the technological challenge, a cementing technology was developed, including a plugging slurry formulation with elastic properties of a cement stone and a casing rotation technology during the cementing process.
The plugging slurry formulation was developed with the elastic properties of a cement stone with cement mixing in salt water, adapted to the conditions of the salinized rocks of the Pripyat trough. To develop the formulation, the simulation of the pressure effect during the development by the P&P method on the cement stone behind the casing was used, as well as the simulation of the process of displacement of the drilling mud by the plugging slurry.
The technology was successfully tested at five sites when horizontal wellbores were fastened with 114 mm tie-back casings, while high cementing quality indicators were achieved. The lengths of the tie-back casings ranged from 509 to 1000 m.
The article presents the results of assessing the quality of cementing using acoustic cementometry and assessing the density of the medium behind the casing by gamma-gamma cementometry, as well as comparing the quality of cementing with casing rotation and without rotation, before and after the impact of P&P development.
In RUE "Production Association" Belorusneft "it was decided to use the developed technology in default for attaching 114 mm liners with subsequent development using the P&P method.
Optimizing Bottom Hole Assembly Design Criteria to Improve Mechanical Performance in Slim Hole Drilling Environment
Authors: Fleming Stephen , Ucero Roberto , Poltavchenko Yuliya 
Published: November 2021

Abstract
After analyzing the historical data of neighboring wells adjacent to the drilling site, 11 bit trips were required due to the low mechanical performance of the bottom hole assembly elements. This observation is based on maximum circulation hours and low helical bucking values that make it uneconomic to drill the sections with a positive displacement motor drive system. A redesign the bottom hole assembly was proposed to achieve an improved mechanical performance which allowed the section to be drilled with a single assembly.
With a focus on increasing the mechanical limitations of the downhole elements, the use of 4 ¾" equipment is considered instead of the 3 ½" standard equipment used in this hole size. One of the biggest challenges was modifying the 4 ¾" positive displacement motor (PDM) to fit into the 5 ½" hole given that the mud motor has a maximum unmodified diameter of 5 ½".
Using the force analysis module of a State-of-the-art BHA modelling software suite, multiple iterations were performed to simulate and validate an alternative PDM design and accompanying directional assembly. This new design featured modifications to an existing 4 ¾" PDM deploying a long gauge bit in combination with a fit for purpose measurement while drilling system.
After numerous runs using this assembly design, it was found that there was no additional or unexpected wear of the modified Mud Motor components or associated elements of the downhole equipment. These observations act to validate the pre-job engineering force analysis.
With the improved mechanical specifications of the 4 ¾" Bottom Hole Assembly (BHA) components, circulating hours were increased from 100 hours to 250+ hours in a stepwise process. This enabled drilling of the entire 5 ½" section with a single BHA, comparing favorably to the legacy approach with an average of eleven bit runs.
The modified 4 ¾" PDM coupled with long gauge bit technology enabled a reduction in the oriented to rotate drilling ratio and an associated increase in the overall rate of penetration (ROP).
It can be concluded that the substitution of 4 ¾" drilling equipment for 3 ½" in the 5 ½" hole section, increased the drilling efficiency between 30-50% according to field data obtained in Ukraine.
The modified 4 ¾" PDM combined with long gauge bit technology has the potential to improve 5 ½" hole drilling performance in other locations. Following a structured planning process using State-of-the-art BHA modelling software suite enabling the evaluation of the significant forces that act in the drilling assembly and so significantly reducing the risks associated with exceeding the original design limits of the assembly. By improving the mechanical performance of the drilling assembly in a 5 ½" hole, new territory for drilling engineers and design engineers is now available to increase the drilling performance in slim wellbores.
Locating Source of Water Production and Performing Cost-Effective Rigless Remedial Operations in Deviated Wells Completed with Standalone Sand Screens
Authors: Timonin Andrey , Mollaniyazov Eldar 
Published: November 2021

Abstract
Wells that are already drilled and producing are the most viable sources of future earnings for all oilfield operating companies. Keeping these wells producing economically at optimal rates throughout their lifetimes is top priority. With time, some oilfield operating companies face with production related problems, such us water breakthrough.
Production logging is well known technique for locating source of water breakthrough in oil and gas producers. In near-vertical, or slightly deviated wells, producing at high rates, traditional production logging tool string can deliver reliable results. On the other side, in deviated wells, producing at small rates, advanced production logging tool is required, due to presence of fluid segregation and recirculation within borehole. Our experience shows that wisely selected logging technique, depending on downhole logging environment, allows to locate source of water production with confidence for planning water shut-off remedial operations.
In wells completed with standalone sand screens water shut-off operation might be complicated as often rig is required for pulling out of hole tubing with sand screens. Another method is to perform chemical water shut-off treatment that might be expensive in some cases. Alternative method is to confirm compact sand accumulation in the annulus and set through tubing bridge plug inside sand screens in wells that producing water from bottommost layers. Plug is deployed in wells without pulling out of hole tubing, as it can pass through restrictions, making this rigless intervention fifty times cheaper compared to intervention with rig.
Field examples, presented in this paper, describe fit-for-purpose logging approach for locating source of water production accurately and executing unique rigless water shut-off operations in cased wells completed with standalone sand screens to increase hydrocarbons production in cost-effective way. After remedial operations we observed significant decline in water production and increase in oil rates in all wells that were intervened.
Overcoming Deployment and Retrieval Challenges with Killed Well Cable Deployed Electric Submersible Pump Systems – Lessons Learned from Five Years of CDESP History
Authors: Xiao Jinjiang , Winaro Mulad , Eissa Mohammas , Mahmoud Akram 
Published: November 2021

Abstract
The advantage of cable deployed electric submersible pump (CDESP) systems are beginning to be understood and realized as experience has been gained with the deployment and retrieval of these systems. Cable deployed ESP systems have at times been touted as a temporary system for failed conventional ESP systems. Long-term successes have demonstrated the value of permanently installed CDESP systems, which provide the benefit of reduced production deferral, less costly change-out, and reduced HSE risk.
The decision to change from conventional ESP to a rigless CDESP system is not necessarily a simple conclusion. The decision must consider technical, economic, and operational considerations to gain the full benefit from the technology. The learnings developed over multiple deployments and retrievals will benefit decision makers in the evaluation of the technology use. The technology application presented in the paper sheds the light on a journey to develop and bring alternative ESP deployment from concept to reality, overcoming technical and operational challenges.
The current CDESP requires a rig to initially construct the permanent completion to accept the rigless CDESP system. Production rates requirements determine the ESP size, and in turn the tubing and wellhead size. Pressure control equipment is installed on top of the Christmas tree. Rigless installation and retrieval of the CDESP is performed on an elevated tower with the wellhead in place. The tower design has been improved to allow the production flowline to remain in place. A minimum of two well barriers, with one barrier well kill fluid, are in place at all times. A key learning of the killed well CDESP system is the need to understand the potential changes to the reservoir after sustained production in planning the replacement of a failed ESP. Kill fluid losses can be higher than expected with restorative well cleanup and production. Actual deployment or retrieval time can be improved with successive change-outs. Long-term operational robustness of the CDESP is proven with a system continuing to operate after 5 years of cumulative operations.
This paper shares the lessons learned from an early technology adopter with multiple deployment and retrievals in various well environments including highly fractured reservoirs and high hydrogen sulfide wells.
Integrating Various Sources of Indicators and Water Measurements Data of Different Degree of Uncertainty: Understanding Aquifer Encroachment and Resulted Water Breakthrough to Gas Producers
Authors: Nashaat Michael , Ghorayeb Kassem , Zhiyenkulov Murat , Shah Abdur Rahman , Lukin Oleh , Madatov Roman , Kolivand Hassan , Grytsai Denys , Filatov Viacheslav 
Published: November 2021

Abstract
Opishnyanske Field is a mature Ukrainian gas field that began producing in 1972 from three formations: Visean, Serpukhovian, and Bashkirian. A reservoir simulation study was implemented to understand the movement of the water in the reservoir and to maximize the field recovery. Some wells showed high water production at their late life and this was the key question that we wanted to understand. If this was a water breakthrough, which means that the aquifer water swept the gas in the reservoir and reached these wells, then there is little potential left in this field. If this was not a water breakthrough, there could still exist some unswept areas to be produced. The second key question was to understand the aquifer strength and direction to be integrated into the simulation model.
The field has different sources of data that could be used to understand the water movement in the reservoir, which are:
Observed production data Water analysis reports (surface water salinity and density measurements) Production logging data Pressure data and geological maps to understand the communication between the wells
Although different sources of data are available, each one has a level of inaccuracy, which was the key challenge. The field also has some other challenges, such as:
Commingled production Contradiction between the observed water/gas ratio (WGR) and water analysis data Limited water analysis data points in some wells Issues with backallocation of the observed data.
Integrating all the available data had a significant effect on understating the water behavior. Data analysis and integration resulted in excluding all the data anomalies and reaching a good understating regarding:
The wells that are showing a water breakthrough Aquifer strength and direction