bluuebunny/crossref_metadata_2025_split huggingface dataset:
Power of 6 Sigma to Overcome Chronic Business Pain Area
Authors: Albusafi Adil , Albalush Farah , Alshuily Mohammed , Albalushi Najim , Alrahali Maadh , Alhinai Ashraf , Alsahlani Ali , Alsalhi Houd , Alkiumi Yousuf , Ram Nayakam , Muhammed Jithin , Maghdari Somaya 
Published: March 2023

Abstract
Production reporting management in oil field has been one of business pain area, with a cumbersome manual allocation process, causing argument over the estimation of produced volumes. Main challenges identified were the inaccuracy of involved meters, multiple production reporting tools, reactive mode decision making, staff exposure during BS&W sampling and Tank dipping. Hence, tremendous integrated efforts using Six Sigma Green Belt Lean approach were made to simplify and sharpen the production reporting process, as well as minimizing the human factor in it.
This project undergone Six Sigma Green Belt Lean project approach as below:
Define stage: define project status, scope in/out, desired status, anticipated business benefits, …etc Measure stage: developed detailed "As Is" process pap identifying all critical X's and data collection plan Analysis stage: developed cause & effect and data graphical analysis (Scattered Plot, Matrix Plot, Box Plot, Dot Plot, Correlation, Regression) Improve stage: generate ideas for potential solutions & prioritization, failure mode & effects analysis show reduction of RPN and Pilot was run where X was optimized accordingly Control stage: developed control plan, standard Operating Procedure (SOP), Visual Management Board (VMB), Leader Standard Work (LSW) & To Be process map and reported business benefits Replicate stage: developed replication candidate alignment & plan
These efforts have resulted in a pronounced business benefit such as:
1.2% Oil Gain 5.7% deferment reduction Full Time Equivalent (FTE) saving of 2.69, which was wasted on various parts of the old methodology Process enhancement of production reporting and making data available which increased the confidence in production data Better focus on low-performing fields to identify surface and subsurface opportunities & bottlenecks Quick, simple & effective solution for operational standard procedure that improved system availability, production gain & team proactiveness Eliminating several high-risk activities by automation several process Early identification of leaks through new developed tools Flare Reduction by early identification of LCV failure and improving measurement system (automated)10% flaring reduction in field-x as result of fixing LCV failure Build the 1st PDO Live Production Management & Monitoring tool which is replicated in other four assets in Oil North Directorate with ongoing replication in the Oil South Directorate.
This innovative 1st PDO Live Production tool is a powerful utilization of the 6 Sigma deep data analysis to insure safe operations of the business processes through:
Optimize operational control systems to eliminate personal & process safety exposure Enhancement of system stability & reduction of trips and human interventions Operating Assets within approved Operating Envelope (OE)
Technical Challenges and Strategic Solutions for a New Historical Milestone: The Success of Delivering the First Two 10 K ft Lateral Wells in an Unconventional Drilling Operation
Authors: Yin Guoqiang , Almasmoom Salahaldeen , Ali Mohammad , Almalki Nawaf 
Published: March 2023

Abstract
To increase the reservoir contact to improve the production, the operator extended the lateral length of the horizontal wells from initial 5 K ft to 6 K ft, then to 7 K ft until 8 K ft. While moving toward a 10 K ft lateral, a bottle neck was encountered and the drilling team had to made all the effort to seek the solution. This paper addressed the main technical challenges to be faced while drilling the first two extended reach 10 K ft lateral wells. Several key strategic solutions corresponding to those challenges were proposed during the planning phase and well implemented in operation. As a result, the first two 10 K ft lateral wells were successfully drilled and completed, establishing a new historical milestone for future operation.
In this paper, the inefficient weight transfer while drilling because of the pipe buckling, wellbore instability, the severe losses of the weak formation, failure to build the curve and difficulties for the well placement in lateral, downhole tool directional tool failure due to the high bottom-hole-circulation-temperatures (BHCT) and the risk of unable to run the production casing to bottom were considered as the main challenges to deliver the 10 K ft lateral wells. To overcome these challenges, according to the established best practice and the available tools or devices that have been already tested and prepared, the drilling team performed profound analysis and established the corresponding strategic solutions for each challenge. This paper described the implementation process of those strategies on the first two 10 K ft lateral wells delivered. The experiences obtained were also addressed.
Artificial Well Engineering Intelligence (AweI): Is It Drilling Engineer's Dream or Driller's Nightmare?
Authors: Samuel Robello , Kumar Kiran 
Published: March 2023

Abstract
Applying artificial intelligence (AI) is exceedingly difficult for drilling operations as the system is overly complex and dynamic. As a result, more comprehensive domain-general engineering mapping, also known as "artificial well engineering intelligence," is required to predict operating parameters and problems with reasonable accuracy. This paper presents a detailed overview of engineering models that are interconnected in the form of microservices to provide a more logical solution as the well is drilled. It draws out some important findings and discusses ways that results can be infused with the work on explainable artificial engineering intelligence in realtime. The results argue the logical reasoning and mathematical proof.
Drilling Engineer–Driller–Rig system interaction through AweI with interconnected subdomains requires tighter integration between various engineering models. To some extent, tractable abstract knowledge at the human level is derived from analytical reasoning through engineering models. Various engineering models are connected in the form of microservices, which can be called any number of times when the optimization is carried out. The results are transferred for physical actions either to the driller or control as set points. The method presented does not claim to address all the issues as a whole. This methodology attempts, however, to present a coherent adaptive model that provides more transparency to the algorithms that can be used as operational parameters for the driller.
The analysis results have shown that the convergence was very quick in obtaining an optimal solution and the predictability in the test wells has shown the best solution results under uncertainty. It has also been found that the results provide reasonable threshold values when increased data is used as the well is drilled. As long as the driller stays within the operational region, the results have shown that the operating parameters are satisfying and good enough for the desirable outcome. In other words, a near-normal engineering solution is achieved.
The two major interacting bottlenecks observed in the study are (1) the absence of domain-expertise and mapping the conceptual space and (2) the valuation of the results, which can be translated into practical operational parameters.
The engineering microservices to derive engineering intelligence include the following: Torsional and lateral instabilities ROP coupled bit wear Hole cleaning Casing wear BHA Drill ahead Mechanical specific energy Hydro mechanical specific energy Motor stall weight (if motor present)
Complex Micro-Containers (CMC) Transporting Compartmentalized Reaction Mixture for Self-Healing Cement
Authors: Baltaeva Madina , Stamer Katerina , Orlov Maxim 
Published: March 2023

Abstract
Zonal isolation and cement sheath integrity are vital for a consistent oil and gas production process in an economic and environmentally conscious manner. However, cement is a brittle material that can fail under repeated application of stresses. The objective of this research is developing a novel material Complex micro-containers (CMC) to induce autonomous self-healing properties to the cement using the mechanism of a self-expanding polyurethane foam formation in a crack area.
Complex micro-containers (CMC) consist of polyol-loaded polyurea (PUa) micro- and nanocapsules loaded inside the isocyanate-filled core of larger polyurethane (PU) microcapsules. The method of CMC creation includes several steps. During the first step, an oil-in-oil emulsion, composed of organic solvent and polyol-polyamine solution, is created. The second step is made of a polyurea shell formation directly at the surface of the polyol droplets controlled by an addition of isocyanate. As the result of the interfacial polymerization process, micro- and nanocapsules are formed. Then, they are mixed with the isocyanate solution and further emulsified in the water-based media. The droplets of isocyanate with micro- and nanocapsules are encapsulated through polyurethane shell formation by adding polyol.
A variety of factors alter the morphology and size of the micro- and nanocapsules including parameters of emulsion's creation, core/shell ratio, and dispersion speed. The optimal content of isocyanate and polyols in cores of polyurea and polyurethane microcapsules, mechanical mixing parameters, and concentration of emulsifiers in oil-in-oil and oil-in-water emulsions were determined. FTIR-spectroscopy was used to identify the chemical structure and to demonstrate encapsulation of the isocyanate core and the polyurethane shell and the polyol core and polyurea shells. TGA-analysis, optical microscopy, and scanning electron microscopy methods were used to determine the core content of micro- and nanocapsules and their size. The peeling strength test proved that the release of the microcapsules’ core content occurs by pressure application and the diisocyanate reacts with polyol and water and creates the polyurethane material.
The main advantage of CMC is its expandable properties due to the formation of a polyurethane foam in the presence of water that can effectively fill the micro-cracks directly in a place of cement breakage. Integration of developed new material into the cement body will allow for improving a long-term wellbore isolation and mitigating a leakage potential in the cemented annuli.
Transforming a Mechanical Vertical Drilling Tool into a Digitally Controlled Rotary Steerable Tool - The Journey of Design, Development, Testing and Commercialization
Authors: Jones Steve , Sugiura Junichi 
Published: March 2023

Abstract
The design and development of a rotary steerable system from inception to commercialization, with proven performance/reliability recognition is an engineering challenge to say the least. Rotary steerable systems (RSS) are one of the most challenging drilling tools to bring successfully to the market. This is because they combine mechanics, electronics and hydraulics that all must operate together to make the system work.
With the complex task and cost of bringing multiple engineering disciplines together on one team (mechanical, electrical, electronic, embedded code, software and test engineers) to develop a rotary steerable, it is often a challenge for a small private company to start from the ground up. In this instance, a completely different approach was adopted to bring a unique RSS to the market.
Utilizing an existing mud operated mechanical vertical drilling tool with slow rotating steering head, the engineering team set to work to develop an electronic control unit with a digital mud valve to transform the tool into a cost-effective rotary steerable tool.
The design, development, engineering challenges, in-house and field-test program will be described to show how rotary steerable development on a budget is possible. Maintaining a tight project budget leads to engineering creativity and thought paths that cannot be inspired when large budgets are subsidizing product development.
The paper will detail how the rotary steerable product was successfully tested by partnering with operators in North America land. Selecting some of the harshest drilling areas for testing increased the pace of development, and improvement was accelerated with the use of multiple drilling dynamics sensors and pressure sensors.
Integration of Geosteering into an Automated Wellbore Placement System, Possibilities and Challenges
Authors: Holbrough David , Forshaw Matthew , Wessling Stefan , Idzerda Saskia , Gelfort Ralf , Austin Simon 
Published: March 2023

Abstract
The benefits of geosteering for accurate wellbore placement in reservoirs are well documented, with an emphasis on comprehensive reservoir mapping capabilities and related well path adjustments. Similarly, drilling-related processes such as well re-design, proximity scanning, and downlinking are important. The integration of geosteering and drilling processes adds complexity and challenges to designing automated wellbore placement systems. Automated systems need to contain sufficiently robust technologies and algorithms to avoid unintended and frequent exceptions. Equally, the human element must be considered to design an automated system with a great user experience. To gain user acceptance, an automated system must have the characteristics of predictability, transparency, adaptability, and automation levels that are validated prior to utilization. Without this, the result will be wellbore misplacement by engineers who blindly trust immature automated systems.
This paper provides an overview of processes and tasks within a comprehensive wellbore placement system, including the directional drilling and geosteering services as used by stakeholders who own well placement execution. We will provide an overview of the potential of automation and pitfalls to be avoided. The experience of many expert engineers from complementary disciplines has been used to develop a comprehensive concept as a framework to implement an automated wellbore placement system.
The paper also provides an analogy to the automotive industry which has developed reliable and robust systems for navigation, lane and speed control over the last few decades. The comparison highlights a fundamental difference to the petroleum industry of having multiple stakeholders involved in the process of wellbore placement. Consequently, communication between all the stakeholders during operations, notably proposals and approvals, must be designed into the system from the beginning.
Automation concepts to achieve great user experience are demonstrated on components of a wellbore placement process, including the illustration of lessons learned from recent development initiatives. Based on the demonstration, we conclude that an iterative development process is essential to ensure acceptance by the user community.
Rigless Repair of Packer Leak Via Annular Cement Plug
Authors: Yugay Andrey , Majed Ahmed Alkarbi Majed Ahmed , Berdiyev Yunus , Utama Indra , Al Hamadi Mohammed Thani , Hassan Karam , Al Marzooqui Afnan , Alshehhi Hajer Mohamed Ali J. , Rincon Gabriel , Al Menhali Shamsa , Ramadan Taha , Al Baloushi Mohammed Sayed , Elhanbouley Sheriff Hassan , Metlyaev Evgeny , Respati Indra , Eliatar Rabie , Setioko Enggal 
Published: March 2023

Abstract
Well double barrier envelope policy is a common industry practice and main philosophy of well integrity discipline. It is well-explained in well integrity related international standards: API RP90 (1 & 2), Norsok D10, ISO 16530 (1 & 2).
It states that all wells with positive pressure at surface capable to flow naturally should have primary and secondary barrier envelope. Primary barrier envelope consists of well equipment which is continuously in direct contact with hydrocarbon and is pressurized. In case primary barrier failure (leak through the tubing, packer, or other completion equipment element), secondary barrier envelope is the one that holds the pressure and prevents further escalation of the incident outside of well boundaries. The content of this paper is related to such kind of wells that comply to the double barrier policy and are equipped with production packers.
Conventional process of curing packer leak is to re-complete the well during rig intervention – the workover. During this process old completion is retrieved and new completion is installed. This operation can be repeated multiple times. Failure of any element of the primary barrier envelope results in the sustainable pressure in annulus "A" – SAP pressure. Such SAP wells is a violation from double well barrier policy and create a hazardous situation.
Performance Envelope of a High-Speed High-GVF Helico-Axial Pump
Authors: Ejim Chidirim , Xiao Jinjiang , Lee Woon , Zabala Wilson 
Published: March 2023

Abstract
Operating a pump at high speeds can have the benefit of increasing the capability of pumps to enhance surface or downhole production of fluids with high gas volume fraction (GVF). This study presents the performance envelope of a high-speed helico-axial pump (HAP) operating at high GVFs (&gt; 80%). The ultimate aim of the physical tests was to ascertain the operating capabilities of the pump for potential scale-up to a field prototype.
The HAP housing outer diameter was 5.38-inch and operated at a rotational speed of 6000 revolutions per minute (RPM). Air and water were the test fluids, with average pump intake temperature of 25°C. The fluid volume flow rates were varied to maintain 50 psig at the HAP intake. The liquid and total intake volume flow rates varied from 128 to 664 barrels per day (BPD), and 4941 to 7593 BPD, respectively. The corresponding discharge pressures and temperatures, as well as electrical power input and current draw to the HAP motor, were also recorded.
The results showed that the HAP had stable operation during the tests for intake GVF range from 91% to 98%. The corresponding pump discharge pressures were in the range of 58 to 101 psig. This indicated the capability of the HAP to boost fluid pressure even for such high intake gas content. The results also showed that HAP boost pressure was positively correlated with liquid volume flow rates, and negatively correlated with the intake gas volume flow rates. Overall, the boost pressure decreased with intake GVF. The electrical input power to the HAP motor varied between 16 to 37 kW. It was observed to strongly increase with increasing liquid volume flow rate, and very strongly decrease with increasing HAP intake GVF. The associated electrical current draw by the HAP motor was seen to vary between 31 and 68 A. Its variation with liquid volume flow rate and intake GVF was similar to those of the electrical power input. In conclusion, the HAP demonstrated capability to boost fluid pressure when handling high GVF flows. It is being scaled up to a field prototype to handle higher volume flow rates of high GVF gas-liquid mixtures.
This study mainly highlights the method to extend the gas-handling capability of a HAP by operating it at high speeds. Optimal hydraulic design and proper conditioning of the inlet flow components were also incorporated in the HAP architecture. Expanding the HAP operating envelope to handle high-GVF flows significantly unlocks the potential for field operators to maximize hydrocarbon production from high-gas content applications. This, in turn, increases the economic bottom-line from the field asset.
High-Density High-Strength Phase Transforming Lost Circulation Material to Cure Severe to Total Losses in Reservoir and Non Reservoir Sections
Authors: Sarmah Pranjal 
Published: March 2023

Abstract
Lost circulation is one of the biggest expenses in terms of rig time and safety in oil and gas well drilling. Uncontrolled lost circulation can results a dangerous pressure control situation and loss of the well. Drilling through large natural fractures is a big challenge. This paper focus on developing high-density, high-strength, Fluid-Gel-Solid based lost circulation material (LCM) using novel surfactant with acid soluble sealant powder to cure the severe losses scenario.
Particulate material, polymer based system, cement, resin etc. has been used as lost circulation mitigation solutions but they have their own limitations of particle size, rheology, tolerance to contaminations, strength to cure sever to complete loss events. A novel fluid system is developed to mitigate these issues. Laboratory customization of the fluid has been evaluated with different temperature and pressure conditions. High pressure high temperature (HPHT) consistometer for setting time, rheometer for rheology and ultrasonic analyzer is used for measuring compressive strength. Tolerance to drilling fluids, spacer and cement contamination also evaluated. This acid soluble system has ease of cleaning if premature gelation occurs.
The fluid has thixotropic properties, viscous under static condition and shear thinning upon pumping, achieved through mixing of novel amphoteric surfactant along with water and sealant powder. This is a phase transforming fluid where amphoteric surfactant forms elongated worm-like micelle structure in presence of monovalent and/or divalent salts. Rheological study conducted to show the fluids elastic behavior and pumping property. This will help to assess the displacement of the LCM fluid. The sealant powder, working as weighting agent, sets hard with respect to temperature and time; and a setting control additive controls the hardening or setting process. Finally a high compressive strength solid plug is formed which can withstand the losses of fluids into the formation. Another added advantage of the system is – it can be optimized with seawater; fresh water is not a limitation.
The fluid technology is based on thixotropic-gelled using novel surfactant that resists the flow and loss of LCM fluid into the fractures once pumping is stopped. Tailor-made system with high-strength acid soluble sealant can be customized for low to high-density fluid formulations as per applications without any additional incremental treatment for seawater.
Investigation of Polymer Latex Effects on Cement Mechanical Properties for Improved Wellbore Integrity
Authors: Al-Yami Abdullah , Al-Qahtani Hussam , Nizar Jaber , Khan Majad , Nawaz Tahir Muhammad , Wagle Vikrant 
Published: March 2023

Abstract
Cement needs to be designed to prevent short-term and long-term gas migration scenarios. In the short term, the cement must prevent gas flow immediately following cement placement. In the long term, the cement must resist pressure and temperature cycling during drilling and production. Wells are subjected to substantial stresses from pressure and well testing, injection and stimulation treatments, thermal effects, production cycling, and changes in the surrounding formation over years. Due to these stresses, the cement sheath damage can occur during drilling, perforation and stimulation, and subsequent production. Polymer latex has been used to help reduce the fluid loss to minimize gas migration and aid in the mixing ability of cement slurries. However, there are some engineers who believe that polymer latex will improve cement mechanical properties.
The objective of this study is to evaluate the effect of polymer latex on cement mechanical properties after curing at elevated temperature and pressures. Experimental work in this study includes formulations at different polymer latex concentrations, densities measurements, rheology measurement, fluid loss testing, thickening time tests, curing for 30 days at elevated temperature and pressure, and finally mechanical properties measurements (Young's modulus, Poisson's ratio and compressive strength). The study shows that polymer latex will improve mechanical properties of cementing which will lead to improved wellbore integrity.