bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrating Process Simulation Modeling and Predictive Analytics to Gain Deeper Insights into Machine Health and Performance
Authors: Minocher Homji Ruzbeh , Bhardwaj Akshay 
Published: November 2019

Abstract
The efficacy of machine learning (ML) algorithms for turbomachinery condition monitoring can be compromised by the lack of robust historical data for training. While unsupervised or deep learning (DL) algorithms may be used when sufficient volumes of ‘labeled’ data are unavailable, they offer limited insights into detected anomalies or outliers. Additionally, the inherent dependency on data volume and variety delays the deployment of these algorithms, making an ML-only approach unsuitable for situations such as a machine's first operating run.
The paper discusses how a combination approach utilizing both first-principle based performance algorithms and ML algorithms can address several shortcomings of the ML-only approach. Examples are provided to demonstrate that one type of algorithm can outperform the other in the detection of specific anomalies. Therefore, when deployed in parallel, they provide the ability to predict / detect a larger universe of machine faults. The combination approach can also address the lack of interpretability inherent to ML algorithms in cases wherein both sets of algorithms show anomalous behavior.
To further address the issue of data inadequacy and poor data quality, the concept of simulation-based transfer learning is introduced. A thermodynamic simulation model is used to generate performance data for a multistage, variable composition centrifugal pump. This data is then used to train two deep stateful LSTM neural network models to predict pump discharge pressure. In the first model only simulation data is used for training while for the second model both simulation and historical data are used.
Prediction results from both models are compared with those from a performance algorithm and an LSTM model trained solely on historical data. Test results demonstrate that the LSTM model trained on both simulation and historical data outperforms the other algorithms. This methodology can be applied successfully to accelerate the deployment and enhance the value of deep learning algorithms for machine performance analysis. An additional benefit of training the model on simulated data derived from well proven thermodynamic/aerodynamic principles, is that the insightfulness of performance algorithms may be ‘inherited’ by the deep learning algorithms.
Applying Brain Science to Achieve Organizational Success
Authors: Al Halyan Dr Amal , Al Badi Abeer , Al Hosani Bashayer 
Published: November 2019

Abstract
Decades ago, scientists believed that the adult brain is fully formed and unchanged. However, it was found recently that the brain is adaptive and can change in both forms: physical and functional forms. This phenomenon is called (neuroplasticity). In simple terms, the neurons (i.e. brain cells) can create newer connections (i.e. physical form) and have better performance (functionality); or go the opposite way. Scientists are greatly interested in this re-wiring characteristic because it can help people with brain injuries to have substantial recovery; and very recently to understand how people can be happier, more engaged and productive at work.
Majority of research available is linking neuroplasticity with how to make employees happier and more productive at work. When people work with positive mindset; productivity, engagement, innovation and creativity improve. However, happiness is still misunderstood as a major drive of performance, due to variety of definition of happiness by scholars (Achor, 2012).
Happiness is a positive psychological state that had been found to be related to work performance and engagement. Work engagement is also a positive psychological state defined by feelings of being energetic, empowered, satisfied and being absorbed in the state of being totally engaged at work (Schaufeli, 2012). Engagement had been extensively studied due to its positive outcome on personal and organizational levels; such as: reduce absenteeism, preventing burnout, increase productivity, having less errors and occupational injuries and accidents, innovation and creativity and having better financial results (Burke & Cooper, 2016).
The following article demonstrates a field experiment which was conducted on approximately 50 employees working in a technical support department for the drilling function in ADNOC Onshore, Abu Dhabi, The United Arab Emirates. The activities are a series of ongoing interactive and team building events that started with the beginning of the year 2019; aiming to provide a positive work environment that enhance bonds between team members, creating positive mindset, and encouraging innovation and creativity.
Correlation Between Drilling Parameters and Geomechanical Properties - The Hidden Geomechanical Information
Authors: Lamik-Thonhauser Bouchra , Schoen Juergen H. , Koller Christian S. , Arnaout Arghad M. 
Published: November 2019

Abstract
The drilling process is fundamentally controlled by the interaction of the bit with the rock which is characterized by its mechanical properties. The focus of various studies is directed mainly on the optimal design of drill bits and drilling operations related to the (expected) geological situation for a safe and efficient drilling process.
The question arises: "Is it possible to extract any rock properties information from drilling data?". In a previous paper the correlation of drilling properties with the lithology of penetrated formation was evaluated. A clear correlation could be demonstrated by applying different statistical methods.
Based on these results a simplified model for the rock destruction at the bit is developed and a "formation strength parameter S" is defined. As a cut-force parameter in the equation, weight on bit (WOB) is used primarily for vertical sections. For deviated or horizontal sections the differential pressure Delta-p is a more relevant parameter. A new parameter S is calculated as a function of drilling parameters only (RPM, WOB, Delta-p, Bit-size). This new parameter S is compared with existing parameters for rock characterization (Mechanical Specific Energy) and discussed herein.
For four wells this parameter S is plotted as function of the depth representing a first geomechanical model. The main results are:
Well A: Geomechanical characterization of different clastic and carbonate sections of a vertical well. Clastic (sandstone, shale) and carbonate (limestone, dolomite) are clearly separated. The carbonate section is detailed and subdivided in dense-hard and fissured-porous parts.
Well B: Calculations are made for vertical (based on WOB) and deviated/horizontal section (based on Delta-p) and compared; for the deviated/horizontal section the Delta-p version gives more reliable results.
Well C: For a specific section of this well after drilling a profile of Unconfined Compression Strength (UCS) with a standard well-logging algorithm was calculated. A comparison of the "during-drilling" derived geomechanical model in terms of S and the "post-drilling" derived in terms of UCS demonstrates similar tendencies and confirms the character of S as a geomechanical measure.
Well D: Data (WOB, ROP, RPM) for this example are logged as part of a test of the new PDS Digital Drilling technology (Powerline Drillstring Technology) in an igneous formation (phyllite). It demonstrates the ability to discriminate different geomechanical sections of one formation.
Unique Fit for Purpose Combination of Three Dimensional Cutters Enabled Operators to Reduce Drilling Cost by Improving ROP and Footage Drilled
Authors: Konysbekuly Galymzhan , James Biju , Lomov Alexander , Gumich Dmitrii , Ungaliev Gaukharbek 
Published: November 2019

Abstract
Finding a safe and efficient approach to drilling in challenging applications is a difficult task for drillers because each field is unique. The industry's common ambition is to use various technologies to increase the mechanical penetration rate and reduce overall drilling time. Most recent studies show that drilling bits play an important role in drilling optimization and help to overcome most of the challenges connected with the rock destruction process and tool lifecycle.
In recent years, 3D PDC cutters such as ridge diamond elements (RDE), rolling PDC cutters (RC), and conical diamond elements (CDE) have helped to further improve the drilling efficiency in a majority of applications worldwide.
The PDC bit brazed with unique 3D cutters moved the industry set benchmark performance standards to the next level by improving cutter durability and efficiency in drilling. These cutters, depending on the shape, can improve ROP, durability, and can improve overall cutting efficiency.
Field tests were conducted in multiple applications with multiple customers in RCA and the authors will present several case studies that will document performance improvement in challenging drilling applications. The results clearly show that the combination of this unique 3D cutter has helped operators to bring a step change in performance by improving ROP and footage drilled. In some cases, operators were able to drill the entire section with the bits equipped with 3D cutter combinations where traditionally more than one bit was used to complete the section. Customization of 3D cutters in the appropriate location of the bit is key to this success.
Downhole Temperature Management in Slim ERD Wells
Authors: Ruzhnikov Alexey 
Published: November 2019

Abstract
One of the limiting parameters while drilling deep extended reach (ERD) wells with 6-in. and less open hole diameter is a downhole temperature (DHT). In such small diameters a temperature can easily reach the limit of existing measure while drilling (MWD) and logging while drilling (LWD) tools and restrict the application of them. The manuscript studies main factors affecting DHT in slimehole application and the ways to manage it, as well as field application of obtained results.
The study of DHT while drilling slime ERD wells started with comprehensive analysis of main sources of heat generation, their contribution to DHT as well as temperature transmission along the borehole. The main sources and factors (as geology, well design and profile, BHA and drill string design, drilling fluid type and design, the drilling practices, ROP, friction factors etc.) were ranked by its impact, followed by the development of the model which could simulate their contribution. Based on the model the prevention and mitigation measures were developed to keep DHT within desired limit during a well construction process.
The study was implemented while drilling slime ERD wells in the fields (Middle East) with static reservoir temperature of 250 - 260 deg F. All the modeling results were confirmed with actual field data proving the validity of the simulations. It was confirmed as well that the downhole temperature management in slimehole application is more complex due to many limiting factors, when main of them are coming either from rock properties, like fracture gradient or downhole tools (for example both are limiting the flow rate which found to be the key player in DHT management).
It was shown that even with all developed measures to maintain DHT in slime wells the limit can be reached in deeper wells, due to limits of the downhole tools available in the industry.
The manuscript describes an approach to do the engineering study of one of the main limiting factors which can prevent drilling of deep ERD wells.
Legal Tips and Tricks for Capital Projects
Authors: Robottom Luke , Tarancon Plata Raquel 
Published: November 2019

Abstract
This paper will consider some of the most common causes that result in major capital projects running into difficulties - including time pressure, inadequate planning, scope changes and communication failures – and will discuss potential ways to mitigate the risk, and help reduce the prospect, of future issues arising and how best to address them if they do (inevitably) arise. In particular, this paper will explore possible internal arrangements – including the involvement of the legal function at all stages of a project (from inception through procurement, execution and finalisation) - and contractual mechanisms which can be used to speed up decision making, reduce the length and complexity of negotiations, manage unexpected events and avoid commercial issues escalating into legal disputes.
Challenges in Custody Metering System in Unstabilized Crude
Authors: Devarajan Umakanth , Chandrasekaran Jagadesh , Paul Raju , R. Kamal Faris , Takieddine Oussama 
Published: November 2019

Abstract
The Design, Installation, commissioning and handover of Custody metering system is very very critical for any project completion. This paper addresses major challenges and the corresponding mitigation methodologies in the design of a custody metering system in an unstabilized crude application in recent Buhasser FFD project.
Custody meter is provided for measuring the Oil production from Bu Haseer Production Separator in Zakum plant at Das Island. The Custody meter is fiscal type and designed as a packaged unit. Custody meter package consist of one working, one standby arrangement and one common pipe proving system. The Metering Package includes the following main equipment and instruments: Coriolis flow meters.Pressure and Temperature transmitters.Proving system with double block and bleed valves.Automatic Sampling systemFlow computing systemInlet/Outlet Valves (MOVs)
The Bu Haseer Oil at the outlet of Custody meter is routed to the existing Zakum Inlet oil manifold which is feeding to all existing Separation trains in the Zakum plant.
A Successful Deployment of Level 4 Multilateral Isolation Completion System
Authors: Al Ansari Nawaf , Racine Baidy 
Published: November 2019

Abstract
In the past, accessing laterals after a multipacker completion system installation in a multilateral well presented significant risks to drilling operations because certain crucial operations, such as acid stimulation, required a rig on location.
Recently, a Middle East operator successfully installed an isolated multilateral completion system. The system was deployed in a well located in an onshore field in the Arabian Gulf region.
The isolated multilateral system was customized for multilateral wells that require re-entry capability to access the lateral. The system provided a completion window equipped with landing profiles and sealbores that enable deflector settings for lateral access or isolation sleeves for lateral control. Additionally, a unique latch coupling allowed for installation at the optimum azimuth and depth of the system for lateral re-entry operations.
Historically, in installations that required access to the lateral, a pilot hole had to be drilled and subsequently plugged and abandoned to avoid running a dual-packer completion, followed by running a single packer as an alternative to enable safe stimulation of the lateral. Using the new multilateral isolation system enabled the first combined observation and producer well with a dual-packer completion string.
The well represented a technical milestone for the service company in the development of multiple reservoir fields. Using the isolated multilateral completion system allowed the operator to achieve the following results:
Maintain accessibility to the observation bore for future monitoring and producing from the other laterals. Improve surface infrastructure by reducing the number of wells to be drilled. Save on drilling and completion costs with individual observation wells. Achieve accessibility through the completion on either lateral independently. Perform acid stimulation treatments using a rigless unit at any point during the life of the well through a multipacker completion. Risk reduction with drilling rigs because critical operations, such as acid stimulation and well testing, can be satisfactorily performed using a rigless unit instead of a rig on location.
The identification of further benefits and lessons learned will be addressed in future work.
In conclusion, the Middle East operator had achieved success in the deployment of newly acquired technology for the multilateral/single-bore completion with multipacker systems.
Field Testing an Accurate, Non-Nuclear, Inline Wet Gas Multiphase Meter
Authors: Annamalai Gautham , Rodriguez Daniel , Soto Marcos 
Published: November 2019

Abstract
In today's oil and gas industry, the importance of accurate measurement of wet gas flows has become paramount due to the recent growth in production costs and continuous fluctuation in crude oil prices. Typical wet gas applications have Gas Volume Fraction (GVF) ranging from 95 to 100 percent and hence the accurate measurement of the phase fractions, especially the water fraction at such low liquid flowrate is a serious challenge. Standard multiphase flow meters were found to be inadequate to operate in such conditions. Hence significant effort is taken by several manufacturers into research and development of ‘wet gas’ flow meters which can accurately measure the three-phase flowrates. Taking on the challenge, an inline non-nuclear wet gas metering system was field tested in Argentina to measure the three-phase flow rates under existing field operating conditions and the results were compared to an existing conventional test separator readings to find out if it can serve as a reliable replacement to the expensive test separator.
Mitigating Challenges during Commissioning and Start-Up of Oil and Gas Projects - Effective Risk Allocation through Appropriate Legal Frameworks / Mechanisms
Authors: Lahiri Shourav , Utuk Raymond 
Published: November 2019

Abstract
This paper identifies and analyses ways in which effective contractual approaches can lay the foundation for mitigating various challenges project sponsors and contractors face during the commissioning of oil and gas projects. It achieves this by reference to specific circumstances that, while often arising in contexts outside of commissioning, raise specific challenges in commissioning scenarios. The paper includes a short case study that is referred to where necessary, along with examples of some drafting which go towards addressing the challenges identified. While there is a lot of literature available on the technical and procedural aspects of all phases of commissioning of large projects (including oil and has projects), there is little in the way of content relating to the role that contractual approaches play in ensuring that the various commissioning risk elements are identified and apportioned accordingly among the stakeholders. This is the lacuna that this paper seeks to address.
Cost-Effective Application of Subsea Production System as Field Development Concept in Shallow Water Environment
Authors: Jamaludin Mohamed Ajmel 
Published: November 2019

Abstract
While the first subsea production system was installed in a shallow water environment (West Cameron field in Gulf of Mexico, by Shell in 55ft water depth, 1961), subsea development concept has been more synonymous with deepwater development. It has not been a development concept of choice for shallow water development in Middle East and Asia mainly due to the perception that it has higher life cycle cost and difficult to intervene.
Subsea production concept can be a competitive option vis-à-vis topsides production concept in certain circumstances. More often than not, project economics dictates that development capital expenditure (CAPEX) requires to be as low as practicable; and pre-investment in the initial phase of the project development needs to be carefully managed to minimize its impact on CAPEX and net present value (NPV). Subsea production system are inherently fit-for-purpose and provide an ideal opportunity for project owners to assess the potential of the particular field before deciding to proceed with full-scale development in the subsequent phase.
The fact that there is a large number of shallow-water subsea production systems installed and operated worldwide in the last 30 years provide sufficient track record, lifecycle cost and reliability data that could be used by field development and front end engineers in coming up with a feasible development concept with attractive NPV.
Subsea production system in a shallow water environment is a proven concept predominantly due to the following factors: Provide alternative development option where fixed structures are not cost-effective:a) Where development costs may not justify the CAPEX for a platformb) Where brownfield expansion requires low well counts Optimize drilling program:a) If field reservoir areas are not reachable by deviated drilling from surface wells, producing hydrocarbon from multiple fixed structures might not be economically feasibleb) Subsea completion and production system offer better flexibility in term of field layout and well top-hole positioningAccelerated development cycle:a) Average 15-18 month to first oil from approval of Field Development Plan (FDP)b) Capital Investment is returned in a more timely mannerMinimize cost on extended well testing-Longer well testing operations from a floating vessel with a lower cost are possibleImproved health, safety and environmental (HSE) performance - Removes people from offshore, potential to reduce visual and environmental impact
This paper will demonstrate that subsea development is a matured concept that can be attractive for shallow water applications.
Intervention-Less Unloading Gas Lift Well Completion Design Using Shearable GLVs and Remote Actuated Barrier Device
Authors: Al Khatib Osama , Mason Jane , Beaman Daniel , Wills John , Brodie Alan 
Published: November 2019

Abstract
The Extended Reach Drilling (ERD) field re-development of a giant offshore field in United Arab Emirates (UAE) from four artificial islands predominantly requires the use of artificial lift (gas lift) to assist in unloading the wells post-completion operations and enhance reservoir production recovery rates. The vision was to achieve a well completion that allows for intervention-less unloading via gas lift using shearable Gas Lift Valves (GLV) and Remote Actuated Barrier Devices (RABD). The key principals in developing a solution to achieve this vision were to reduce rig time by avoiding critical path unloading, minimize post-rig activity to install live gas lift valves, and eliminate HSE exposures. Historically producer wells were completed with dummy gas lift valves and a frangible barrier device to facilitate the required completion pressure testing and provide barriers for rigging down from well. Coil Tubing (CT) was used to break the barrier device and kick off the wells with nitrogen. Once gas lift is available, the wells would be shut in, and a series of wireline interventions carried out to replace the dummy valves with live GLVs. This time consuming and costly process increases in cost when subsequent rig location covers the well that needs intervention; critical path rig time has been needed to unload wells with CT, in some cases requiring up to seven (7) rig days. This resulted in increased construction cost of each well and additional HSE exposure associated with the rig-less interventions required.
A method was developed to deploy the upper completion with live, barrier qualified Tubing Pressure Shearable GLV’s (TSGLV) and a RABD, which enables all necessary well-construction integrity tests to be performed, and subsequently convert to a production configuration to allow unloading, gas lift and production of wells. Post-completion, well unloading and gas lift is immediately available without incurring critical path rig time or rig-less interventions.
In this paper, the authors will demonstrate the technology that was developed, the qualification and testing program that was implemented, and final solution that enabled the Company to deliver wells successfully with remotely actuated unloading and production without the need for intervention.