bluuebunny/crossref_metadata_2025_split huggingface dataset:
Excellence Execution During Challenging Phase an Apple and Banana Principle
Authors: Mishra Kishore , Satheesh Bindu 
Published: November 2020

Abstract
Will oil and gas operating companies or EPC industries attempt to invest in a new project in this difficult market situation, when they are not sure about the success of the projects due to high uncertainty of the market and changing priorities of the market? Any success of the organization/project expects business value such as measurable improvement to revenue, profits or net income, automation to improve productivity, new product release, reduce inventory costs or some other targeted outcome. Our paper delves into the interconnection between the above two statements.
The Standish Group 2015 CHAOS Report (ref-1) states that, out of 50,000 projects in the study, 71% failed to meet the major success factors viz: on time delivery, completion within budget, and satisfactory results. The problem is even worse for big projects. When 91% of Medium-sized projects failed, the failure for larger projects reached a whopping 94%. That is scary since PwC reported that capital projects and infrastructure spending between 2014 and 2020 could reach $29 trillion. Does this mean that $27 trillion is at some risk? That's crazy! Are we doing anything about this? This 71% failure rate reflects the expected outcome of all project including small, medium, and large.
A project/organization that does not meet or exceed expected business value is considered as a failed project/organization. Our view of project success is relatively straightforward. If you do what you are asked to do as per the project scope, then you should be on time and on-budget. If you deliver what you have committed to deliver, then you should achieve or exceed the business value promised. Of course, this is in the assumption that the bid is made properly. Proper bidding is very important for the successful execution of the project up on award. Clear understanding of the scope, identifying the major risks if any, defining the execution strategy including the execution centers (100% local, 100% overseas or blend of local and overseas execution centers) etc. are the important aspects that should be well thought of and defined in detail in the proposal submitted to client. An efficient hand over of the proposal to the execution team up on award should be done to ensure that the assumptions, execution strategy etc. are effectively communicated to the execution team.
Computational Fluid Dynamic Modeling For Hazardous Gas Dispersion Analysis In Deepwater, Brazil
Authors: Franklin Gabriel , Barros Wagner , Ceciliano Marcos , Cunha Jeferson , da Rocha Aquiles , Fagundes Diego , Margotto Romulo 
Published: November 2020

Abstract
The production of hazardous gases such as CO2 and H2S impose high risks to offshore operations, with lethal impacts on personnel, along with special equipment required and environmental challenges. Hydrocarbon productions require that part of this gas could disperse on the atmosphere, so a comprehensive risk analysis is necessary to evaluate the gas disposal event. Computational Fluid Dynamic (CFD) can be used to effective study how the wind and environment can interfere with the gas dissipation in the air. In this work, a specific analysis was necessary to produce a gas well with up to 80% CO2 fluid composition. A CFD Gas Dispersion Analysis evaluated the turbulent airflow over and offshore drilling vessel perimeter to map the flammability levels and hazardous gases concentration zones, depending on winds speeds, wind directions, and well gas flowrates. Parallel processing was applied in order to reduce the computing time for simulation of 52 cases on gas release on burner booms and relief lines, and 56 cases for leak analysis on the process plant. The results permitted defining using 3D maps the concentration levels of hazardous gases on the rig expected on each scenario condition, as well as the coverage area outside the vessel affected by the gas release.
Planning and Challenges of Longest Complex 3D ERD Well Drilled in United Arab Emirates Onshore Field Artificial Island using Slim Casing Design
Authors: Hashmi M. Asef , Salem Gamal , Morales Annie , Banihammad Basma , Al Yamani Sultan Mohamed 
Published: November 2020

Abstract
This well was drilled with the objective to support the pressure sustainability of multiple producer wells across Lukhweir-2 formation based on ERD approach. This paper presents the challenges faced in planning and drilling of subject ERD well with a total measured depth of 27,352ft (8.34km) and having horizontal hole of 11,300ft (3.45 km reservoir contact) with directional difficulty index (DDI) of 7.208 using light/slim casing design.
Planning of this well started by meetings and collaboration with asset team to a common objective of delivering the longest well across Lukhweir-2 (LK-2) reservoir to support the multiple producers and mitigate all the associated risk by proper planning and drillability analysis such as trajectory design, collision risks, BHA, hydraulics and casing designing. This paper will explain the novel approach of mitigating the challenges faced while drilling this ERD well such as concerns about surface hole drilling (30 deg across interbedded shale formation), challenge in running 7" long liner (&gt;8000ft across multiple reservoir) and overcoming surface pressure and torque limitations while drilling. Results, Observations,
This ERD WAG injector well is the first and longest to be drilled with 6" drainage across Lukhwair-2 reservoir from artificial island to have 11,300ft of 6" Geo-Steered Horizontal hole section using Slim Casing design which gives the total well measured depth of well 27,352ft MD / 10,101ft TVD (2.7 ERD H:V ratio) Results from this well have proven that ERD wells with longer reservoir contact have significantly improved well performance, enhanced reservoir management and reduced field development cost. This paper summarizes the practice and technology used to drill successfully the longest ERD / MRC well using slim design practice which includes the utilization of special dope for 4" DP to increase the torque limit, use of special surface equipment called chillers/coolers to over overcome high downhole temperature. This paper will also capture the drivers, selection criteria and lessons-learned over the entire well drilling.
The challenges/mitigation explained in this paper will stretch the ERD/MRC boundaries and support engineers to design the complex 3D wells with slim/light casing design and can achieve extended targets with 100% integrity.
The Operator's Eyes Downhole: Multiple Applications for a Novel Autonomous and Wireless Real-Time Integrated Monitoring System
Authors: Bezerra de Melo Ricardo Cesar , Eid Ramy N. , Tubel Paulo , Pasupathy Praveenkumar , Martinez Zuazo Iker 
Published: November 2020

Abstract
Nowadays wells are drilled deeper, hotter, and subjected to higher downhole pressures making it more complex for completion, deployment of production tools, and to maintain long term well integrity. It is evident that the utilization of downhole data is becoming more important, to optimize production, maximize the recoverable reserves, and to preserve the proper structure of the wells, facilitating their full life cycle until decommissioning. The Energy industry is relying on new technologies to reduce the cost of exploration, production, and maintaining the wellbore's structural integrity for the duration of the well-life as well as the reduction of their decommissioning cost.
This paper addresses various new opportunities created by an "integrated" casing/tubing/microsensor technology, and real-time data communication from downhole to the surface. This manuscript will highlight some of the main components of this Novel Autonomous and Wireless Real-time Integrated Monitoring System, which consists of: A smart casing-collar module with an array of various sensors, to monitor casing/cement for the initial state of stress, formation creeping, open annuli and near-wellbore reservoir properties. This information is processed through a short-hop, two-way wireless communication system, for data and command transfer from the casing module to the tubing module, and a wireless power transfer system, to provide power from the tubing-module to the casing-module.An intelligent tubing module deployed near the smart casing-collar module that contains another set of smart sensors for production and annulus monitoring. Interfacing with the casing module is done via the short-hop wireless power transfer and communications system. Included here is a downhole power generator and a real-time wireless communication for data transfer to surface. This provides the end user, the ability of in-situ power generation and real-time wireless data.
The abovementioned integrated system is aimed at addressing the entire well-life planning needs, as it can feed the asset management system for production optimization, zonal isolation, P&A placement, casing integrity, formation creeping, reservoir evaluation, and potential decommissioning requirements. Custom-specified systems can quickly adapt and incrporate new features that are of potential benefit to other "industries".
Artificial Intelligence Based Optimization of Gathering System
Authors: Lakshmanan Charan , Muralidhara Srikanth , Karajagi Nachiket , Chakraborty Somdatta 
Published: November 2020

Abstract
Gathering system optimization is no longer an option for any operator, it is a necessity. The primary objective for an operator is to match the demand at the sales point to avoid penalties due to minimum volume commitment (MVC) agreement.
With time, operators face challenges to adhere to this demand due to inefficient production surveillance, production optimization & capital project evaluation. Also, with oil & gas price at its lowest, operators are now facing increased cost pressures leading to less personnel for field operations.
Operators are now collecting & managing a lot of data than ever from their operations as part of their digital journey, which enables them to improve the network performance using machine learning. Insights or details missed by operators or conventional first principle-based models can be derived & explained using these models.
The paper talks about this novel approach of machine learning-based collaborative platform called ‘Digital Twin’. Digital Twin is based on automated data flow from ingesting data from SCADA system, pushing required data to the steady-state simulator, receiving simulated results, & finally viewing the machine learning augmented simulation results on the platform.
In this solution, the Bayesian Changepoint model is trained on wellhead flowrate & line pressure to identify critical wellpads & pipeline sections needing intervention, in real-time.
Deep learning-based neural network algorithm is then integrated as part of the digital twin to accurately predict the scenario of field changes. This neural network algorithm is trained on the actual field data along with steady-state simulation results. The model output helps the operator to identify the deviation of the simulation results from actual field data, then improving the simulation results for certain scenarios of field changes.
The improvement in accuracy by about 15% was realised with the neural network structure of 5 layers (3 hidden layers + input layer + output layer) through its machine learning augmented simulation results. With improved accuracy, operators are accepting the solution to make real-time operational decisions through the automated architecture resulting in a 95% reduction in time for simulating scenarios.
This paper aims to provide a blueprint of the digital twin solution & explaining its potential for easy scalability across different gathering networks.
Using Data Science to Enable Condition Based Maintenance and Classification for Offshore Assets
Authors: Subrat Nanda 
Published: November 2020

Abstract
Recent advancements in the field of data science, digital technologies and their applications are presenting new opportunities for marine and offshore fleet operators to adopt a more effective asset management strategy that combines advanced data analytics with maintenance and operational experience to reduce unplanned downtime. Advanced data science and analytics enable timely detection of deteriorating equipment behavior, which in turn optimizes the scope of maintenance activities and planning based on asset condition. When used within a reliability-based maintenance program, they further provide the foundational elements for building an enhanced platform for efficient risk-based decision making and better understanding of asset health and performance. This information can be useful for classification societies to be able to make better class related decisions and make the class experience more targeted for operators.
New Insights on the Interaction of Stick-Slip and HFTO Shown in a Case Study in North Sea
Authors: Heinisch Dennis , Kück Armin , Hohl Andreas 
Published: November 2020

Abstract
Drilling tools are subjected to mechanical loads while drilling, resulting in loss of performance due to accelerated wear and subsequent tool damage. Two special phenomena are well known to generate high mechanical loads in torsional direction: Stick-Slip and High Frequency Torsional Oscillations (HFTO). Preceeding studies have explained the nature of the interaction of these phenomena, how they can superimpose and how stability maps define safe combinations of operational parameters. This paper will provide a systematic and quantitative study of these effects based on high-frequency measurements recorded during a North Sea deployment.
In this paper, for the first time, an in-bit high frequency measuring device is used to validate the theoretical modeling of the stick-slip-HFTO interaction. Field data from the North Sea including surface and MWD measurements are used in a broad study to investigate the influence of operational parameters, bit and formation on the torsional dynamics over the increasing depth of a well. Pure Stick-Slip, pure HFTO as well as the development of HFTO within a slip-phase of stick-slip is observed, described and compared to the theoretical model describing self-excitation. Several hundred instances of stick-slip are used to determine characteristic RPM thresholds for combinations of RPM and WOB. The totality of these thresholds compose a stability map indicating zones of reduced torsional loads.
The study shows that stick-slip amplifies torsional loads generated by HFTO up to a certain RPM threshold. Further increasing the RPM leads to reduced loads for certain combinations of bit, formation and operational parameters. In contrast to common belief, higher RPM can lead to lower torsional loads in certain scenarios while also increasing ROP. The stability map summarizes the learnings, indicating zones of safe operation in an accessible manner.
The resulting stability map can be used by operators to navigate in stable regimes of operational parameters. This reduces wear, tool damages and enhances drilling performance.
Maximizing Mature Offshore Field Value by Using Auto Gas Lift Technique
Authors: Grifantini Simona , Saqib Talha , Sabri Abdel Mouez , Keshtta Osama M. , Albadi Bader S. , Beaman Daniel J. , Al-Hassani Sultan D. , Bigno Yann , Draoui Elyes H. , Bansal Bhagwan D. 
Published: November 2020

Abstract
The giant heterogeneous carbonate field presented here consists of multi-stacked reservoirs and is located in the Arabian Gulf approximately 135 km north-west of Abu Dhabi. The reservoir named "T" measures 9 km by 11.5 km, with large accumulation of 35 °API oil with initial gas oil ratio of about 400 scf/STB. The current reservoir pressure is around 2,700 psi; many of wells are unable to flow naturally against the high sealine pressure, due to low productivity and relatively low GOR. To produce these wells, "artificial lift" or lower sealine pressure are required.
A collaborative team of Reservoir Engineers, Petroleum Engineers and Geoscientists was assigned to find a sustainable and cost-effective solution to produce reservoir "T" in order to evaluate its potential. The team conducted a detailed and comprehensive study of the field starting from reservoir "T" and then expanded to the other reservoirs. As a result, the proposal of an "Auto Gas Lift" (AGL) pilot was formulated to use gas from the reservoir "C" (underlying reservoir T) to artificially lift the oil produced from reservoir T.
AGL is a cost-effective artificial lift system, directly replacing for conventional gas-lift equipment, gas compression facilities, gas transport pipelines and ancillary equipment. This technique has been identified as the most suitable for such mature offshore field, where existing platforms have limited spare load and space capacity and could not accommodate gas-lift compression facilities or ESP topside equipment. The first pilot completion has been designed. It consists of a perforated downhole high GOR zone from which gas is bled into the tubing at a rate controlled by a downhole gas lift valve. The gas produced from high GOR reservoir C will allow reservoir T to flow by reducing the hydrostatic head of the fluid column in the well.
Artificial lift has not been implemented yet in the field. However, several artificial lift techniques, such as Electrical Submersible Pumps or conventional gas lift, are foreseen in long term development plans. "AGL" technique, if successful, could represent a cost-effective solution for further appraisal of this reservoir, without waiting for the implementation of large-scale artificial lift techniques.
Full Automated Casing Running: The Next Step Completed in Field Automation
Authors: De Mul Arthur 
Published: November 2020

Abstract

Objective
Although the drilling industry is slowly moving toward a higher degree of automation, casing running is still left out of this equation. Until now. Due to the more delicate handling that is required to handle casing, the task is often handed over to dedicated casing running service companies. This year, a new rig is build that performs the task of casing running, including making and monitoring the connection, fully automated and 100% hands off: "just press start sequence".

Methods
To enable full-automated casing running, it is required to have a dedicated handler with high precision handling and measuring systems. To reach the maximum safety level, the goal is set to have no people in the red zone on the floor for any assistance.
An integrated (scada) control system needs to combine data as casing length, positioning, amount of turns to spin in and make up torque into one system. It also needs to communicate to the other rig equipment as drawworks and topdrive to enable smooth fully hands off operations.

Results
The above is this year integrated in an HM100 mobile rig and will be deployed in the oilfield in Q3 2020 for a mayor operator. The equipment is capable of handling casing up to 13 3/8" in full automated sequences at a speed of ∼ 1300 ft/hr, more then 300% faster then manual operations.
At a traditional catwalk machine, casing is pushed over the pipe slide. For this reason the thread needs to stay protected by thread caps, until the pipe is in wellcentre. Here usally 2-3 people are present to guide the casing and apply dope etc. To make sure that no people need to work in the red zone on the floor, it is chosen to develop a pipe handler that lifts the casing from pipe bed to wellcentre in one movement, while keeping the thread clear: a massive safety improvement.
The sequence is completed by an automated hand over to the casing running tool on the topdrive.
As final step, while making the connection, the integrated torque turn graph system controls and monitors the connection and stores this combined with the length in the auto-tally system.
Fast save operations, with data readily available.

Novel
This is the industry first mobile rig with full automated casing running capabilities, an important step in the ongoing field automation. With a consistent speed of over 30 casings / hour the time per well is reduced significantly, while there is no need to have separate crews and tools available on location. Casing running will now be predictable in time and duration, with real time results immediately available on the OPC-UA server for the client.
The Digital Transformation Journey from Digitization to Opportunity Generation
Authors: Makanjuola Oluwafemi , Meroney Pat , Gray Max 
Published: November 2020

Abstract
Throughout the history of subsurface exploration, the energy industry has acquired, recorded, and archived extremely valuable subsurface data (including new data) on legacy and new media such as round reel magnetic tape (14-track, 7-track, 21-track, 9-track, etc. circa 1950s), square cartridge tape (3480, 3490, 3590, 3592 series, LTO series, 8mm, 4mm, etc. circa 1980s), optical media (CD, DVD, etc.), and hardcopy documents. The physical media are boxed, inventoried and stored in climate controlled salt mines and/or warehouses. Pertinent media with high priority datasets are recalled from storage, transcribed, and made available for processing, interpretation, data rooms, etc.
The challenges associated with the physical storage construct of these assets include residual storage and shipping costs, pace of deterioration of legacy media, delayed access to requested dataset, valuable data locked away and inaccessible, amongst others. To combat these challenges, ExxonMobil initiated a strategic, upstream wide, digital transformation partnership with Katalyst Data Management whose mission is to increase opportunity generation by reducing the turnaround time of high priority datasets and providing access to previously undiscoverable data.
The digital transformation partnership leveraged the latest tools, technologies, and techniques including enhanced metadata capture, live/automated QC, parsers and loaders, data analytics, automated metadata extraction, etc. In addition, petroleum data management standards and best practices were employed across the digitization value chain.
The digitization of nearly 3 million hardcopy paper or mylar documents and more than 420,000 seismic tapes to date (as of July, 2020) has eliminated recurring physical storage costs, recovered valuable data from deteriorating media, shortened access to high priority datasets from weeks to hours, and provided access to previously undiscoverable "dark" data. Other digitization ‘wins’ include the elimination of the need for ExxonMobil to maintain facilities and hard drives to read physical media. This strategic partnership between ExxonMobil and Katalyst Data Management has led to the convergence of digital data from multiple physical data sources and data types, all on a single integrated subsurface domain agnostic platform. More importantly, it has enabled Artificial Intelligence and Machine Learning use cases bringing about business insights and leading to prospect opportunity generation.