bluuebunny/crossref_metadata_2025_split huggingface dataset:
Automatic Realtime Monitoring of Drilling Using Digital Twin Technologies Enhance Safety and Reduce Costs
Authors: Rommetveit Rolv , Gholami Mayani Maryam , Nabavi Josef , Helgeland Stig , Hammer Raymond , Råen Jostein 
Published: November 2019

Abstract
As part of the digital transformation in oil and gas industry, well construction move toward new efficient methods using digital twins of the wells. This paper will highlight how the drilling operations are monitored, how a digital twin of the well is utilized and how learnings are implemented for future wells.
A Digital Twin is a digital copy of assets, systems and processes. A Digital Twin in drilling is an exact digital replica of the physical well during the whole drilling life cycle. Its functionality is based on advanced hydraulic and dynamic models processing in real time. By utilizing real-time data from the well, it enables automatic analysis of data and monitoring of the drilling operation and offer early diagnostic messages to detect early signs of problems or incidents.
In the current study various actual operational cases will be presented related to different wells. This includes using digital twin during drilling under challenging circumstances such as conditions when using MPD techniques. Also, various diagnostic messages which gave early signs of problems during running in the hole, pulling out of the hole and drilling will be presented. High restrictions were detected using comparisons of real-time values and transient modelling results. These will be discussed.
Different real cases have been studied. Combining digital RT modelled and real-time measured data in combination with predictive diagnostic messages will improve the decision making and result in less non-productive time and more optimal drilling operations.
The Role of Advanced Polymers and Basecoats in High Performance Oil & Gas Coating Systems
Authors: Pernice Guglielmo 
Published: November 2019

Abstract
Over the past forty-five years, thin dry film lubricant (DFL) coatings have continued to evolve to meet continuously changing industry requirements, by introducing novel polymers and coupling them to traditional basecoats. In the case of thin film coatings (~1 mil/25 um) the pairing of these components is especially critical in selecting the proper coating system for the specific application. The objective of this paper is to highlight the proper pairing of these topcoats and basecoats to address material performance expectations and operational requirements.
Historically we have seen the Energy sector use numerous variations of DFL coatings to deliver consistent coefficient of friction (CoF), antigalling and low breakout torque properties. While DFLs have gained wide applicability from bolting to blowout preventers (BOP's) they remain thin films and susceptible to corrosion and mechanical damage unless paired with the proper base coat/primer/pretreatment. An overview of corrosion performance of the coating system via ASTM B-117 will be presented. Furthermore, some of the additional operational requirements which affect topcoats (i.e. abrasion, UV, temperature performance) will be explored based on selected novel binder polymer topcoats.
The results will identify the performance of the coating systems based on singular operational performance requirements, in a variety of environments. These will include corrosion performance expectations with real environment, where possible, with results demonstrating corrosion performance based on the proper pairing of topcoats with Zn Phosphate, Zn Plate, Zn Ni, ceramic metallic and novel Zinc Flake basecoats. Additionally, results will identify the proper topcoat based on UV, abrasion, and thermal operational characteristics using comparative testing standards such as ISO cyclic standard, Taber abrasion and polymer thermal oxidation testing. Tests and results will include and compare PAI, PPS, Polyesters, modified Epoxy systems, as well as novel high temperature Solgel coatings to address the proper positioning of these coating within the proper application performance requirements.
As operating environments and expectations change, coating suppliers will continue to adapt and incorporate new polymer technologies and formulate coating systems, which address the ever-changing industry challenges. Novel coating systems that will be introduced range from the high temperature (800°C) Solgel ceramic like polymer with usage in heat exchangers as antifouling coatings, as well as zinc flake basecoats, which are proven to be effective thin-build high corrosion resistant coatings with conductivity capabilities and lubrication incorporated, meeting API 20E performance requirements.
Innovative Application on Dual Oil Producer Completion: Gas Lift for Lower Zone and Natural Flow for Upper Zone Extends Oil Production in Giant Middle Eastern Oil Field
Authors: Barragan Ernesto , Al Mulla Abdul Naser , Bazuhair Mohamed , Alshalabi Alaa , Cornwall Rachelle 
Published: November 2019

Abstract
A giant oil field consisting of carbonate reservoirs in onshore Abu Dhabi has been provided with long term Field Development Plan, including several Dual Oil Producer (DOP) completions in formations Shuaiba and Kharaib, more specifically in zones A & B to maximize oil recovery. Upper Zone and Lower Zone B have been producing on natural flow using dual completions. This has been possible due to high reservoir pressures available since the beginning of the production.
Conditions have changed, especially for the Lower Zone B, and reservoir pressure has been declining for the past years. As a result, several wells ceased to flow mainly due to lower pressure and/or higher water cut conditions. Therefore, Gas Lift has been selected as the preferred artificial lift method in lower zone B.
The problem has been identified in current dual wells where Upper Zone is still producing but changing dual into Gas Lift single oil producer in lower zone B will translate into halt in oil production in upper zone, therefore reducing the oil recovery for Upper Zone. This is a consequence of the current practice of plugging and abandoning the Upper Zone.
An innovative application for dual oil producer completion with Gas Lift mandrels in long string has been evaluated to keep both zones producing and extend the ultimate oil recovery of the current wells. Candidate selection, including analysis and workflow, will be presented in detail. Moreover, the design process, well modelling and installation will be addressed further in this paper.
Innovative Emulsion-Suspension Systems Based on Nanoparticles for Drilling and Well Workover Operation
Authors: Sergeev Vitaly , Tanimoto Kenji , Abe Masashi 
Published: November 2019

Abstract
A scientific research results represented in this paper show significant improvement of the applied nanotechnologies in the area of oil and gas fields development. Deep experimental research has been done in the period 2017 - 2018 with the goal to create the most environmental and efficient blocking-agent for loss-circulation control and well-killing operation with a minimum negative impact on the natural reservoir system, downhole equipment and surface systems for collecting of oil and gas. The carried out experimental work mainly based on the coreflooding tests which are showed a high-efficiency of the application of nanoparticles with the modified surface for generation of an emulsion-suspension system with incredibly high surface activity and stability properties which can be easily regulated by change the ratio of phases of the emulsion-suspension system [1–7].
The coreflooding tests proved the possibility of the developed emulsion-suspension systems to reach the ultimate blocking effect even in the super-permeable hydraulic fractures with the permeability and conductivity more than 400 Darcy. Four specially developed modifications (samples) of the emulsion-suspension systems with different structure and content of solids have been invented and tested. The results are showed that the blocking effect can be regulated in a wide range of the geological and physical parameters of the petroleum reservoir by change the ratio and type of solids and liquids in the system. The application of the emulsion-suspension systems provides minimal decrease of the hydraulic fracture conductivity - 67 times and the maximum - 7833 times. The synergetic effect of the compositions of solids with different surface charge provides an opportunity to reach reversibility of the blocking effect into the petroleum reservoir system. The reversibility of the blocking effect assures recovery of the rock productivity for hydrocarbon phase. The surface charge of solids makes a positive impact on the wettability of the rock surface. Also, in the paper disclosed laboratory equipment and methodology of the coreflooding tests carried out on the models of hydraulic fractures.
Big Data Insight towards Well planning, A case study
Authors: Akoum Mohamed , Enrique Roswall , Izmeqna Ashraf , Al Nuaimi Seena Mohamed , Waheed Aasim , Kumar Pranav 
Published: November 2019

Abstract
There are various factors that contribute to the Well planning. Be it cost, complexity of the reservoir, safety measures, isolating problem areas, engineering, etc., The whole process of well analysis takes a lot of time and efforts, as the method used is mostly manual. In this abstract, we explain the Big Data approach used to perform Well Planning which significantly reduces the drilling engineer time. Future, possible suggestions to the existing system are also discussed in this paper.
Over the past few years, the concept of Big Data has gradually matured. Drilling Engineers, Data Management and the Solution Development Team have jointly discussed the potential and the functionality if this concept to optimize the Drilling Engineer performance and timeframe for preparing and delivering drilling programs for the new development wells. EDM (Enterprise Drilling Management System), drilling suite of applications, In-House drilling data extraction tool with Web based interface, and many different types of excel sheets, were considered as the input sources. Well planning process was automated for offset and related data acquisition, results and knowledge were captured in a central repository, which will be used in future endaovers.
Fig 1. Shows existing architecture and proposed roadmap to develop a robust system for predicting the new drilling well location. For example, all the data related to NPT records for the wells in the delimited area, their reports, and daily drilling records were brought together. Then, a cutoff value was decided and color coding was used to highlight wells near the offset wells. This layer was overlaid on GIS map to see the exact location and on the In-House web based tool. The criticality was highlighted using the color code. Based on the above, this solution aims to enhance the drilling engineer performance and represents a major contribution towards increasing the efficiency, as wells as the improvement of the drilling operations. In Future, the team plans to add more complex algorithms based on refining the search criteria, extracting data for the offset wells and implementing Artificial Neural Network. The team is also working on connecting corporate datastore for the exploration, production, and development data to EDM. As of now, the EDM is connected to Corportate database through views to access Directional surveys for Wells. Bringing all the data types and sources together has made the analysis of offset wells simpler. The process is more automatic and efficient. It has transformed the process from having local copies of the data, copying data from different sources, and manually applying formulas and generating reports into a centralized repository, in addition to dynamic and automatic reporting. It also, introduces better accessibility from different drilling engineers for enhanced communication, collaboration and knowledge sharing.
Advances in Surface-Wave Analysis Using Single Sensor Seismic Data and Deep Neural Network Algorithm for Near Surface Characterization
Authors: Alyousuf Taqi Yousuf , Colombo Daniele 
Published: November 2019

Abstract
In hydrocarbon exploration, seismic surface waves are used to characterize the near-surface by imaging the subsurface shear wave velocity for geo-hazard investigation and near surface seismic corrections to avoid false structures in the final seismic image. Surface waves, identified in a conventional surface acquisition experiment, can be analyzed in the frequency wavenumber (FK) domain to generate dispersion curves at each shot location. The subsurface shear wave velocity is represented as a 1D profile with lateral variations can be handled using laterally constrained inversion or by applying spatial interpolation of 1D results. We identify two fundamental challenges to perform surface wave analysis. First, inadequate sampling of the surface wave in conventional sensor arrays may create artifacts in the frequency-wavenumber domain, which introduces further distortion in the signal. The use of broadband single-sensor single source land 3D seismic data provides adequate sampling of surface wave energy that is captured with negligible aliasing and high signal power. This makes it possible to record fundamental and higher surface wave modes at large frequencies. Second, it is common in seismic exploration to deal with large amounts of seismic data on several tens of thousands shot gathers of the single sensor survey making manual picking of dispersion curves a tedious and time-consuming job. We developed a deep belief network (DBN) with multiple hidden layers to pick fundamental modes in the phase velocity spectrum. The neural network workflow was trained on 1500 gathers and validated on several 100 gathers. Finally, the automated picking was applied to roughly 50,000 gathers using frequency range (3-30 Hz). The resulting dispersion curves show high spatial correlation and are geologically consistent. The fundamental mode pseudo-section shows smooth changes with significant lateral variations of Rayleigh-wave phase velocities. The second and third mode of dispersion curves are observed in some shots in the F-K spectrum but usually they have weaker energy than fundamental mode. The recent advances in surface wave analysis is presented over a complex structure where the raw data are characterized by strong Rayleigh waves dominated by a fundamental mode. Dispersion curves were inverted using nonlinear conjugate gradients to generate a shear wave velocity model with high vertical resolution for the first 50 m depth. The recent development in seismic data acquisition using single sensor broad band data, and advances in seismic processing using deep neural network lead to a novel technology that enable automatic picking of dispersion curves.
Revised Industry Guidance on Managing Safety Critical Elements
Authors: Scanlon Mark 
Published: November 2019

Abstract
Many organisations operating in the high hazards industrial sectors have process safety management (PSM) systems in place; but what does PSM mean in practice when there are many safety risk reduction measures to manage, and are some more important than others?
The objective was to improve capability of managing safety critical elements (SCEs) by revising the established 2nd edition industry’ technical publication ‘Guidelines for Management of Safety Critical Elements’ (Energy Institute 2007).
Through a cross-company collaborative Energy Institute working group, industry was engaged in a technical development project to capture experience in SCE management since publication of the 2nd edition (Energy Institute 2007). Whilst The term SCE originates in the UK E&P sector legislation, experience is that SCE management concepts in the E&P sector have since been applied internationally across Europe through to Australasia, driven by a European Directive and national requirements, respectively. In addition, industry engagement showed that SCE management concepts also have been applied beyond the E&P sector to petroleum refining and bulk storage, and conventional (thermal) power generation.
The 3rd edition (Energy Institute 2019) has updated the 2nd edition (Energy Institute 2007) so as to: capture industry experience in SCE management; make it applicable to a wider range of facilities, and recognise the range of maturity of international legislation and competent authority requirements for SCE management, which include some that mandate verification through to those with little specific requirement for MAH management. In doing so, the 3rd edition provides: new guidance on SCE development and management in project phases, from initial SCE suitability through to ongoing SCE suitability; new guidance on the role of human and organisational factors in SCE management; new guidance on management of change (MoC), which is a challenge to SCE management; additional guidance on developing performance standards (PSs); additional guidance on assurance aspects of SCE management, to address an imbalance with the amount of guidance on verification; new guidance on implementation of SCE integrity assurance, such as its interface with maintenance management; new guidance on SCE management at system, equipment and component levels; new guidance on determining SCE criticality; new guidance on SCE performance, review and continual improvement, and new guidance on SCE ageing, obsolescence and life extension. In addition, the 3rd edition provides practical examples to support the guidance.
The 3rd edition (Energy Institute 2019) provides a robust and updated ‘industry’ benchmark of good practice in managing SCEs for organisations operating in the high hazards industrial sectors. Adopting its guidance should enable them to ensure initial and ongoing suitability of SCEs, and so contribute to improving their PSM capability.
Pushing the Limits of Depletion Optimization Towards a Hybrid Field Development Plan in a Complex Giant Offshore Carbonatea Reservoir – Comprehensive Scoping of Technical and Economic Viability
Authors: Obeta Chukwudi , Al Dhanhani Helal , Balakrishnan Selvam , Kosik Ivan , Hermann Rolf , Ibrahim Dahir , Nguyen Minh , Shekhar Ravi 
Published: November 2019

Abstract
The subject reservoir is a geologically complex Lower Cretaceous carbonate system, which is on water flood recovery scheme. Due to extreme diagenesis and associated geologic heterogeneity (which include faults, fractures, burrows and algal floatstone), water breakthrough occurred early and oil recovery is low due to water channeling and by-pass of huge volumes of un-swept hydrocarbon. The low recovery performance is compounded by the relative thinness of the reservoir as well as unfavorable mobility characteristics due to disparity in oil and injected water viscosity. The unique interplay of geology and fluid properties confer special displacement characteristics to the reservoir, which despite extensive literature review for similar architectures in a wide range of geologic settings yielded limited results. Despite previous recovery enhancement efforts through workovers, well spacing optimization, and horizontalization, water production has steadily increased. As a key growth contributor in a massive Brownfield re-development project, the reservoir is currently undergoing intensive drill campaign been executed from artificial islands. The strategy underpinning the redevelopment effort involves holistic evaluation, optimization and selective application of innovative well completion technologies, including MRC (Maximum Reservoir Contact), EMRC (Extended Maximum Reservoir Contact), Trilateral, Fishbone, ICV (Inflow Control Valves) and Infill for low-drawdown depletion concept. For Fishbone, the considered design parameters include branch angle, length and numbers. Branch displacement from the mainbore was a key design assessment for Trilateral in view of the potential for injection support buffering by the flank branches. For the Infill, optimizations include spacing and timing. A new ICV logic was implemented on a full field basis to assess incremental opportunity capture through flow restrictions in high water flux intervals. Layer placement sensitivities assessed which zone placement configuration maximizes targeted sweep of bypassed oil. The life cycle production forecast of various completion scenarios per drainage pattern were compared among themselves utilizing technical and economic criteria for identification of the completion that generates maximum value leading to the generation of a hybrid full field, life cycle optimized development plan consisting of MRC/EMRC, Trilaterals, ICVs and infill wells which are currently been executed.
Asset Value Maximization through a Novel Well Completion System for 3d Time Lapse Electromagnetic Tomography Supported by Machine Learning
Authors: Dell'Aversana Paolo , Servodio Raffaele , Bottazzi Franco , Carniani Carlo , Gallino Germana , Molaschi Claudio , Sanasi Carla 
Published: November 2019

Abstract
In this paper, we introduce a new technology permanently installed on the well completion and addressed to a real time reservoir fluid mapping through time-lapse electric/electromagnetic tomography while producing and/or injecting. Our technology consists of electrodes and coils installed on the casing/liner in the borehole/reservoir section of the well. We measure the variations of the electromagnetic fields caused by changes of the fluid distribution in a wide range of distances from the well, from few meters up to hundreds meters. The data acquired by our technology are processed and interpreted through an integrated software platform that combines 3D and 4D geophysical data inversion with a Machine Learning platform equipped with a complete suite of classification/prediction algorithms. Every time new data are acquired, they are fully integrated with the previous database, and used for decreasing the level of uncertainty about the dynamic model of the reservoir. In order to clarify the potential impact of such system on reservoir management, we apply this methodology to a synthetic data set. We discuss a simulation of a scenario where the waterfront approaches the wells during oil production. The goal of our test is to show how to combine our technology with Machine Learning to make robust predictions about the water table variations around the production wells.