bluuebunny/crossref_metadata_2025_split huggingface dataset:
Special Issue on Fluid Powered System and its Application
Authors: Takaiwa Masahiro , Noritsugu Toshiro , Tsukagoshi Hideyuki , Ito Kazuhisa , Tanaka Yutaka 
Published: October 2020

It is well known that fluid-powered systems are used practically in almost all industrial fields, including construction, manufacturing, transportation, among others.
Nowadays, the rapid growth in the development of the mechanical elements in fluid-powered systems, such as control valves, actuators, and sensors, and the rapid growth in control strategies have given rise to pioneering in some novel application fields in ways that were thought to be impossible a decade ago. High-precision positioning control using the compressible fluid of pneumatic driving systems and multi-legged robots equipped with standalone hydraulic components are simple examples. Moreover, soft robotics based on fluid-powered technologies has attracted attention not only in academia but also in human support fields, which will become more important as Japan’s society ages.
This special issue on “Fluid Powered System and its Application” includes one review paper and 22 other interesting papers related to the state of the art in the development of mechanical elements, total drive systems, motion control theory, and concrete applications of fluid-powered systems.
We thank all of the authors and reviewers of the papers and hope this special issue helps readers to develop fluid powered systems that will contribute to developments in the academia and industry.
Research of high strength steels bending
Authors: Tаmila V. A. , Nesterovich M. L. 
Published: October 2020

The article deals with the issues of obtaining high-strength steels. A conclusion about the effect of the temperature on the steel was drawn based on the research of the microstructure. To check the effect of the welding process on the steel under study, the hardness of the weld and the zone of thermal influence were measured. The weld was checked by X-ray television control for defects in the weld joint.To analyze the possibility of free bending with local heating experiments on tempering samples were conducted in order to identify its optimum temperature at which no cracking occurs in the steels after bending. Bending experiments were carried out after local heating.A comparison of the results of measuring the hardness of the weld, as well as samples obtained after tempering and local heating of the bending line were made. Graphs of the drop in hardness of the studied steel depending on the tempering temperature, as well as the drop in hardness as it moves away from the local heating line, are constructed. Bending experiments with compression of high-strength steels were performed using a substrate material.The samples obtained during the experiments were examined by X-ray for defects in the bending line. The value of compressive stresses acting on bent sample is calculated.
Utilizing Agile Approach for Well Construction Planning
Authors: Kussanov Ilyas , Puche Ernesto , Yung Kyle 
Published: October 2020

Abstract
An Agile well construction planning method was implemented to aid in a significant cycle time reduction for the completion of all necessary steps in technical design and review in well plan delivery. By utilizing this novel method, 8 fit for purpose well plan packages were completed and delivered in 3.5 weeks. While traditional process is often characterized by multiple, interdependent sequential steps and as such, can typically take 1-2 months for a single well. This prolonged timeframe is incompatible with an ever-fluctuating market environment and as such, a more rapid, well delivery method is required in order to deliver significant cost savings in a competitive price environment.
The Agile well planning approach deployed incorporated iterative and incremental development processes enabling decision making to be employed efficiently with a high degree of quality to any responding changes. This novel planning approach is based on working in self-organized, multi- disciplinary team, responsible for developing a project incrementally by periodically reviewing, assessing and applying any required course corrections to meet the project goal. It works by splitting the whole project into parallel tasks called ‘swimlanes’ that incorporate clearly defined individual timeframes, entry and exit criteria for each work item. This is opposed to the traditional waterfall method of delivering a final product only at the end of the planning phase, which may require lengthy rework if market and operational conditions change. The Agile well planning process resulted in the delivery of high quality and up to date well programs through synergies found in dynamic integration of geological, economical and engineering data. Interactive review provided us with a quick 1-day response to any changes while planning without major reworking of past material.
The result of applying these best practices helped in improving well planning documentation delivery pace from 1.5 wells per month to 8 well per months. This was achieved by the full integration of different disciplines, avoiding repetitive tasks and providing management more influence on the inflight product. Therefore, application of the novel Agile management approach in well construction planning allows more rapid well delivery whilst still maintaining quality in the final deliverables.
Digitalization of Simple Things Cost Savings from Basic Transformation Case: Karachaganak Field
Authors: Bekbossynova Anara , Bekniyazov Yermek 
Published: October 2020

Abstract & Introduction
"Transformation are hard and digital ones much harder…"
Digital transformation has been on the agenda of all organizations for many years across Oil and Gas industry. It has proven that digital transformation can bring various benefits to day-to-day operations and cost reduction.
In this paper, we will explore the impact of «digital transformation of simple things» on cost savings opportunities in operations. Data in this paper are based on the successful real cases of KPO's* digital projects implementation, which resulted in minimization of paper-intensive processes, and maximization of automated workflows.
This paper primarily focused on simple things (projects) transformation such as streamlining document management, enhancing business processes, warehouses management, and office environment.
General approach based on the KPO's Roadmap. The Roadmap consisted of detailed digital opportunities for basic transformations that linked with organization's principles such as agile philosophy (managing projects and teams for transformation of basic day- to-day activities that allowed "eliminating redundant" processes, continually providing feedback, learning and reacting quickly to change), sustainable development, and others. Processes in the Roadmap focused in the simple things changes (transformation) which are based on real digital cases.
*Karachaganak Petroleum Operating B.V. (KPO) - is a joint venture between Royal Dutch Shell (29.25%), Eni (29.25%), Chevron (18%), LUKOIL (13.5%) and KazMunaiGas (10%). KPO oversees the expansion and development of the Karachaganak field – one of the world's largest oil and gas condensate fields. Located in northwest Kazakhstan it covers an area of over 280 square kilometres and holds estimated hydrocarbons initially in place (HIIP) of 9 billion barrels of condensate and 48 trillion cubic feet (tcf) of gas, with estimated gross reserves of over 2.4 billion barrels of condensate and 16 tcf of gas.
Case Study: IoT Production Intelligence Platform and its Field Implementation Results
Authors: Sultabayev Arkhat , Jilmagambetov Dauren 
Published: October 2020

Abstract
Application of digital oilfield solutions and widespread of Internet of Things (IoT) is getting more often in various oil and gas processes, especially for Production Optimization purposes. Rapidly developing technologies consistently taking a more significant role in forming an effective Production System. Oil and Gas Producers are going through different stages of the technology deployment: from well automation systems (SCADA) to the introduction of intelligent well control algorithms. Demonetization of technologies, in conjunction with a competitive technology environment, creates the best pre-requisites for widespread Digital Oilfield solutions (DOF). Years back, due to high investment costs, the payback period for the DOF was on a long-term scope, then nowadays it's possible to set KPIs with a short payback period. This article discusses the latest production optimization platform and real results of recent implementations in Kazakhstan.
Managed Pressure Drilling as an Advanced Solution for Deep HTHP Wells and Long Intervals with Narrow Safe Pressure Limits
Authors: Krivolapov Dmitry Sergeevich , Magda Andrey Vladimirovich , Soroka Taras Bogdanovich , Dobrokhleb Pavel Yurievich , Evdokimov Stanislav Aleksandrovich , Gagloyev Georgy Georgievich , Novoselov Aleksandr Vadimovich , Ramazanov Aynur Ravisovich , Attia Mohamed Samir , Zvyagin Vasiliy Fedorovich , Nabiullin Renat Ildusovich , Khamidullin Denis Radikovich 
Published: October 2020

Abstract
Managed Pressure Drilling technology became popular and widespread in Western countries in the early 2000s and has long been successfully used for drilling complex wells onshore and offshore projects (for example in the North Sea, Gulf of Mexico and etc.) In Russia this technology has found its application relatively recently and still has never been used for offshore drilling.
This article describes the results of the first MPD offshore application in Russia for drilling an HTHP exploration well in the Caspian Sea. A fully automated MPD set with early kick detection system (EKD) and back pressure pump (BPP) was applied, allowing to control pressure and drilling fluid outflow besides drilling, during connections. The drilling conducted using reduced mud weight in «near balanced» conditions, which compared to conventional strategy sufficiently reduced formation overbalance and losses risk as well.
Specialized MPD tests used to determine formation and fracturing pressure limit in uncertainty geological conditions, optimizing core sampling drilling and mud roll-over strategy.
Well Placement Helps to Manage Large Structural Uncertainty While Drilling a Horizontal Well in S Nurzhanov Field, Show Case from Kazakhstan
Authors: Adilbekov Kairat , Kozov Kairat , Mukanov Erlan , Chzhen Igor , Karychev Yakov , Nevzorov Ruslan , Makhambetov Aman , Ospanov Dastan , Shozhikov Daulet , Lukpanov Akimzhan , Medvedev Maxim , Alexeev Konstantin 
Published: October 2020

Abstract
When drilling horizontal wells, geological uncertainties have a much greater effect on the fulfillment of geological tasks than when drilling vertical wells. The combination of the classic geosteering methodology, complemented using logging while drilling (LWD) technologies, and rotary steerable systems, allows you to quickly make decisions on changing the well trajectory to optimize the entry into the target formation. During subsequent drilling within the target formation, the use of multilayer mapping technology in conjunction with an extended LWD and RSS system - helps to more accurately adjust the position of the horizontal section in the reservoir, thereby increasing the rate of reservoir penetration
This article describes the effectiveness of the geosteering service to reduce structural uncertainties of landing of the transport section and while placing a horizontal section in the productive part of the S. Nurzhanov field. Structural uncertainties were mainly caused by the proximity of the regional fault to the horizontal section and the variability in the thickness of the target intervals in the offset wells.
The provided geosteering service made it possible to complete all the tasks set for drilling the horizontal section, preventing the exit from going beyond the target zone and avoiding the unwanted approach of the wellbore to the unproductive rocks lying within its boundaries.
Re-Visiting the Project Risk Management Framework and Adapting it for the Kazakh Oil and Gas Industry
Authors: Syzdykov Murat , Seitimov Talgat , Baibussinova Zhanar 
Published: October 2020

Abstract
Risk management has become of the utmost importance in the industrial world as it provides a common ground between opportunities and risks by addressing project uncertainties. In addition, inadequate risk quantification and management have a significant impact on the decision-making outcome and the success of the project. The aim of this research is to review existing literature on risk management, evaluate and rank selected resource-related risks, and propose a framework for the Kazakh oil and gas industry.
Traditional risk assessment considers risks from two perspectives: the probability of occurrence and possible consequences of a risk event. These two indicators are further multiplied to estimate the risk index. This research followed the same method, but took into account the preliminary qualitative step of correctly evaluating likelihood and effect of risks. We designed a questionnaire of 15 factors, divided into equipment, labor, materials and exogenous categories. The survey was then distributed to project engineers and management professionals working in the local oil and gas industry.
Price fluctuations, delays in delivery of materials, change orders, slow mobilization of equipment and its failures are identified as the most serious risks. These factors are also indicated the greatest in separate probability and impact rankings. Moreover, research findings demonstrate that the likelihood of occurrence of incompetent labor and equipment shortage is closely correlated with their possible consequences at statistically significant level using the Pearson test. Change orders and price volatility have once confirmed their importance. Finally, respondents described the amount of contingency as an indicator of a risk mitigation strategy.
The suggested framework is practical for the industry and increases the chances of success of oil and gas projects in Kazakhstan and the entire region. Complex projects have a high level of technological, organizational, and informational challenges and uncertainties and are heavily resource-dependent. The combination of experts, decision-makers, and stakeholders’ judgments and statistical interpretation tools provides additional insights into the nature of risks. This study sheds light on such an important topic and improves current risk management practices.
Wastes Injection Projects in North Caspian Sea Area
Authors: Galiyeva Gulnara , Gaz Ivan , Francia Luigi , Kuanyshkaliyeva Maigul , Yeskaliyev Nursultan 
Published: October 2020

Abstract
Wastes injection when implemented correctly allows reducing environmental impact and in many cases reducing projects costs. However, often such projects suffer the support from regulators, local communities as well as have little interest from technical professionals. The goal of the paper is to reduce the fear of wastes injection by sharing the acquired experience on waste injection project challenges and opportunities.
The paper describes subsurface aspects of wastes injection projects in stages of feasibility and implementation, performed by operator for the offshore area in North Caspian Sea and onshore area in western part of Kazakhstan.
The operator investigated several wastes injection opportunities in different time. Drill cuttings injection (DCI) was studied for two locations in the past and a pilot DCI project was successfully implemented in 2013-2014. Wastewater injection possibilities were studied for onshore locations for water injection from processing facilities. Currently the operator is pursuing the project, which will allow using a DCI well for the injection of wastewaters generated offshore.
Naval Architectural Challenges in Kashagan Oil Field Development
Authors: Putorti Emanuele , Cuomo Giovanni , Bridges Robert 
Published: October 2020

Abstract
In the early 2000, a consortium of Oil and Gas Companies operating the Kashagan, a super-giant oil field located in the North East of Caspian Sea, Kazakhstan area, embraced the challenge of maritime transportation in ultra-shallow waters, combined with a 5-months ice season per year and the potential risk of exposure to sour gas as a result of a blowout. The paper will present the ad hoc solution studied, tested and implemented for the first time in the naval architecture literature.
A fleet of bespoke vessels was designed, model tested in the ice tanks of internationally recognized research centers, constructed and successfully tested in real scale in the field. For such vessels, unique of their type, Classification Societies were involved through all project stages, in order to comprehend these new technical characteristics, thus issue a new set of Class Rules accordingly. A multidisciplinary activity of reverse engineering was performed, involving Environmental, Metocean, Ice Engineering and Naval Architecture teams, starting from the probabilistic forecasted of the ice thickness, its temperature and corresponding actual tensile strength. Vessels structure and propulsion power were dimensioned as a direct consequence of that, allowed to achieve minimum weight, hence minimum draft.
Such approach resulted in the construction of 2 highly specialized prototypes: the Mangystau, an ultra-shallow ice breaker for marine logistics supply chain, capable to break up to 1m level ice and navigate at 2.5m draft, as well as and the IBEEV, Ice Breaking Emergency Evacuation Vessel, intended to execute the task of EER - Emergency Evacuation Response, capable to rescue up to 340 people in ice infested waters, with the presence of an H2S toxic gas cloud. These pioneering vessels continue to support the development of the Kashagan oil field today.
The novelty of the above is mainly constituted by the nonstandard approach to the problem, exploring for a new way to apply technology rather than applying an existing one, which resulted in the realization of vessel prototypes and the publication of new set of Class Rules.
Integration of Surface Facilities Constraints with Reservoir Model for Sulphur Production Management in Kashagan Field
Authors: Nogerbek Nurbol , Bukharbayeva Aigerim , Ali Samad , Amangaliyev Bagdad , Shambulov Mustafa , Hatiboglu Can 
Published: October 2020

Abstract
Kashagan oil field has been under production since September 2016. The produced oil is associated with considerable amounts of sour gas that must be processed or disposed of while minimizing flaring. This paper will focus on the methodology for field development planning and production forecasting, incorporating gas reinjection and sulphur management with the objective of optimizing production, subject to operational constraints and bottlenecks at surface facilities.
The field development plan includes reinjection of associated gas into the reservoir to increase oil production capacity at the surface and provide reservoir pressure support, while satisfying government regulations that do not allow continuous gas flaring. This requires analysis of H2S concentration and sulphur production, since the ultimate surface constraint at Kashagan field is sulphur processing capacity.
We describe reservoir modeling workflows for oil production optimization with integrated logic for gas balancing. The impact of sulphur management on oil production is studied under different scenarios using a high resolution, fully compositional reservoir model.
The procedures for management of the production facilities have been translated into reservoir simulation logic, including product streaming from facilities and processing constraints. This includes gas accounting and prioritization of gas with low H2S content to be processed at the sulphur recovery unit. The remaining gas with higher H2S content is sent back to the injection stream.
Workflows have been developed using tailored scripting with user-friendly input of facilities constraints using spreadsheets to enable the model to be maintained in a ‘live’ state. Automatic allocation methods are used for prediction forecasting that penalize higher gas production wells but still provide incremental oil production. Development of a product streaming model allows for reporting of production of liquefied petroleum gas (LPG), dew-pointed gas, etc., in addition to the standard simulation results.
The comprehensive guidelines provided in this paper can aid reservoir modeling and surveillance for a field through accurate analysis of actual operational constraints and bottlenecks as part of the planning process. The described gas and sulphur management logic provide pivotal information to enable the reservoir engineering and production teams to meet the challenges of development planning for a sour reservoir.
IPSM for Production Forecasting and Production Optimization in Giant Carbonate Field Kashagan
Authors: Bukharbayeva Aigerim , Hatiboglu Can , Mtchedlishvili George , Munsyzbayeva Dinara , Uap Berik , Muftakhidinov Baurzhan 
Published: October 2020

ABSTRACT
This paper describes the application of Integrated Production System Modelling (IPSM) at Kashagan field. The IPSM is used for short-term, mid-term production plan and business plan forecasting, opportunity identification/validation and production optimization.
The IPSM modeling strategy is to build fit-for-purpose model which produces accurate results with minimal running time. IPSM enables integration of surface network (GAP) and reservoir simulator through Resolve by Petroleum Experts. This in turn helps to replicate actual field performance by incorporating field management logic (script) and modeling relevant system constraints. While there are many constraints governing the maximum production in Kashagan field, they can be summarized into two main constraints: injection capacity and sulphur processing capacity. Modeling of the latter is essential to consider the impact of composition change over time.
As a result of continuous improvement of existing model and close collaboration with multiple teams, IPSM model has proven its prediction capability with forecast accuracy of 99%. Current IPSM model is able to produce results for various streams: oil & gas production, gas injection, Sulphur throughput, etc.
Additionally, IPSM demonstrated its importance in identification and evaluation of various production opportunities / threats as well as its need in influencing management decisions. After calibration of pipeline network to match actual data, a substantial potential opportunity of optimizing existing wells capacity was revealed. This is vital not only for short-term production optimization needs but also for long-term predictions.
This paper presents several case studies and examples of application and value of Integrated Production System Model in the field. Learnings during implementation of a given feature are also described. Provided examples can be useful for other engineers practicing Integrated Production Model suite.