bluuebunny/crossref_metadata_2025_split huggingface dataset:
Quantitative Integration of Seismic and Electromagnetics for Enhancing Subsalt Imaging
Authors: Turkoglu Ersan , Colombo Daniele , McNeice Gary , Sandoval-Curiel Ernesto 
Published: November 2018

Abstract
Thick salt sequences characterized by halite concentrations embedded in evaporitic and clastic layers can form a seal for hydrocarbon accumulations. Prospect generation in this geology involves accurate imaging of the evaporitic package, underlying deep basin structures and the basement. Robust seismic velocity model building in salt geology is a challenge and, at the same time, a mandatory requirement for obtaining accurate seismic depth images of the subsurface. Electromagnetic (EM) methods provide the additional independent structural and rock-physics constraints needed to generate robust velocity models through a numerical integration method called joint inversion. Multiphysics datasets were acquired over three blocks in the study area including wide azimuth seismic, magnetotellurics (MT) and controlled source electromagnetics (CSEM). Wide offset, multi-frequency and multi-component CSEM and marine MT complement each other to map the 3D resistivity distribution from the seabed to several kilometers depth. The resistivity information from EM inversion was utilized to enhance seismic velocity reconstruction though a hierarchical and multiscale joint inversion approach iterating over model dimension, frequencies and offsets. Seismic traveltime residuals and a cross-gradient function, mapping the structural similarity between velocities and a previously derived CSEM/MT resistivity model, are simultaneously minimized through the joint inversion approach to enrich the velocity reconstruction with structural details contained in the resistivity model. As a result, a better velocity description is obtained for the key geological features such as: the top of the layered evaporitic sequence (LES), the flanks of the salt diapers, and of clastic packages within the LES. The new depth-domain seismic images provide enhanced imaging of key geological targets such as the base of salt and the underlying basement structures that are superior to seismic images derived from a seismic-only velocity model building workflow.
Clay Free Invert Emulsion Drilling Fluid System- An Innovative Rheology Modifier Which Provides Flat Rheology for Deep Water Drilling and Viscosifier for Clay Free System
Authors: Patel Arvind , Indulkar Sakshi , Chavan Vikas , Maddheshiya Pradeep , Asrani Megha , Thakur Swapnil , Singh Anil Kumar , Gupta Vivek 
Published: November 2018

Abstract
Exploration and Production Operators prefer a non-damaging non-aqueous fluid (NAF) for drilling Reservoir. One of the requirements of non-damaging system is a clay free system and it should perform as good as any NAF Fluid. For drilling in deep water environment, it is necessary to have flat rheology of NAF over a wide range of temperatures. An innovative polymeric rheology modifier was used to develop Clay Free Invert Drilling Fluid (CFIDF) which provides dual function to achieve a clay free system as well as flat rheology when measured over a wide range of temperatures from 40 to 150 °F.
The flat rheology is required in offshore deep water drilling due to varying temperature profile from 4 °C at the bottom of sea to as high as 100 °C or even higher at bottom of hole. Lower temperatures increase the rheology leading to higher ECD and at higher temperatures the rheology is lowered leading to hole cleaning issues. Flat rheology profile minimizes or eliminates such adverse effects on ECD or hole cleaning activity.
The newly developed clay free system utilizes a single rheology modifier component to provide dual functions of providing true clay free system and offers flat rheological profile without sacrificing the vital mud parameters such as emulsion stability, fluid loss control and rheology. In addition, the system uses a new rheology modifier that provides a temperature-independent rheology profile for hole cleaning, barite suspension, ECD management. The system can be formulated for deep-water applications with mud weights up to 18.0 lb/gal and bottom hole temperatures up to 350°F.
Recent successful field trials as a clay free system for drilling reservoir indicated that the new system is easy to maintain and provides good fluid performance in terms of drilling rate, ECD management, lost circulation control and hole cleaning. The product provides an excellent rheological profile and was used in the field at a low dosage of 1 ppb. Even at this low dosage LSRV was above 10 in 8 ½″ Hole with yield point of greater than 15 lbs/100 sq.ft. When the system was contaminated with a severe saltwater flow, there were no fluid-related problems before the synthetic/water ratio was restored. The new fluid system exhibits flat rheology profiles and non-progressive gel structures. The system showed excellent hole cleaning with excellent thixotropic properties. This resulted in a noticeable reduction of lost circulation potential in lost circulation prone areas due to manageable ECD.
An innovative rheology modifier which provides clay free system and offering flat rheology profile has been developed and successfully used in field. The rheology modifier can minimize or totally eliminate the organophilic clay to improve the quality of non-damaging reservoir drilling fluid.
Multi Source Data Analysis To Improve Drilling Efficiency, Reduce Costs and Enhance Performance Monitoring
Authors: Zausa Fabrizo , Pellicciotta Luca , Spelta Andrea , Bruni Valerio , Baio Fulvio , Medea Alessio , Rossi Nicola 
Published: November 2018

Abstract
A huge amount of data is made available during well operations (surface and downhole logging data, lithological reports, drilling reports, equipment data,.). An integrated analysis of these multi source data provides highly valuable information for future wells engineering and planning in term of well problems investigation, performance enhancement and, ultimately, cost reduction by anticipating and reducing risks.
The use of a "big data" solution consolidating these multiple sources allows the creation of numerous analytics both on single well and group of offset wells. Particularly, the interpretation of surface logging data through the automatic recognition of operating sequences, when put together with other data sources including standard daily reports, provides a much higher granularity than traditional reporting.
Every operation is accurately measured through objective and detailed KPIs (ROP, tripping speed, weight to weight, connection time, etc.). Technical and performance issues are easily evaluated allowing a better understanding of their root causes, anticipating and avoiding the occurrence of these problems in the next wells and measuring activities and operations potential improvement.
This process helps reducing drilling costs through entire well lifecycle:
The calculation of the technical limit and the implementation of the lessons learned that can emerge from the analysis allows to increase the performance on the overall drilling phase through the reduction of the Invisible Lost Time. ILT are usually around 25% of all the drilling operations. This increase of performance has been measured on a series of drilling campaigns in a range from 6% to 8% time saving. The calculation of impartial performance indicators is already used on some drilling contracts, to incentivize performance from drilling contractors and also to cover excessive low performance. Up to 5% of contract value can be adjusted thanks to these KPIs. The extensive use of well data improves the quality of reporting information from the field. It provides also a structured repository of all data recorded from the well operations. This digitalization process opens a world of capabilities for the operators in terms of predictive modelling and operations automation.
The novelty of this approach is the combination of multiple data sources that provide unmatched analytics. In fact, these data are usually analysed on individual basis and limited to control in real time drilling operations. Therefore, the approach is creating value out of existing data, with limited resources.
Reduction of Sulfur Species in LNG to Ultra Low Levels
Authors: Ali Nafisa , Abdulla Haitham , Al Ameeri Ahmed , Jacques Manuel , Kouaiche Ilhem 
Published: November 2018

Abstract
ADNOC LNG and TechnipFMC are reviewing options to reduce total sulphur in LNG, from a current realized specification of 4-9 mgS/Nm3, down to less than 1 mgS/Nm3. The requirement is to enhance the quality of the LNG product, and reduce environmental emissions.
Several technologies were reviewed, including options to hydrolyze COS present in wet sweet gas, introduction of desulphurization beds downstream the dehydration units, and changing the type of molecular sieves. Those options were extensively reviewed, and found to be inadequate on their own. Therefore, solvent swap within the Acid Gas Removal Unit (AGRU) along with Molecular sieve upgrade was found to be the most viable option.
Rigorous efforts were put in place to establish a robust roadmap that serves furnishing the correct basis, defining the required assessments and developing the intended approach and tools.
This paper aims to present the overall methodology, approach and efforts undertaken to study the means to reduce sulphur species in LNG, in the present three LNG trains.
Digitalization of a Giant Field – The Rumaila Story
Authors: Salman Yaser , Gauder Denis , Turnbull William Bill 
Published: November 2018

Abstract

Objectives/Scope
The Rumaila Operating Organisation (ROO) is a consortium made up of BP, China National Petroleum Corporation (CNPC) and the Basra Oil Company (BOC) formed to manage the rehabilitation and expansion of the Rumaila super giant oil field, considered the third largest in the world. The Digital Oilfield (DOF) plays an important role in the rehabilitation process. This paper describes the major challenges, solutions and benefits over 5 years of implementation.

Methods, Procedures, Process
The development of the DOF solution involved several components: the installation and connection of sensors; a data management platform for both real-time and non-real time data; the development of engineering models and workflows; an Exception-Based Surveillance engine (EBS) and a user interface integrating all this data.
This paper details how an EBS process is handled for a field of this magnitude, the use of state-of-the-art algorithms for identification of well flow conditions, deployment of advanced analytics for surveillance and optimization of natural flow and ESP wells.
This paper also details how usability testing and advanced graphic design practices were used to guarantee maximum adoption of the new toolkit.

Results, Observations, Conclusions
The Rumaila case is ideal for evaluating the added value of digitalization of oilfields since the project developed from a zero base to a fully digital system in a matter of a few years. The main success stories include: the extension of the lifetime of the ESPs; reduction in well downtime; significant time savings for repetitive tasks; improved reservoir management accuracy; the ability to more readily meet production targets; facility management and optimization; and improvement in oil quality.
The data and visualization usage figures which are continuously monitored show a year-on-year growing user base. This demonstrated that maintaining focus on continuous development and evolution, and providing top class support locally and from specialist vendors, increases user adoption.
As a result, the program has gained support at all levels in the organization, making DOF an integral part of the field operation providing high efficiency and standards of excellence.

Novel/Additive Information
Due to the initial lack of any digitalization in the field, this project can be considered a blueprint for modernization of fields in challenging environments, where very little digital infrastructure is initially available. This project has proven that DOF implementation can be very successful despite many localized challenges, and that a continuous focus on system evolution guarantees a growing user base year after year.
From Insight to Foresight: Knowing How to Apply Artificial Intelligence in the Oil & Gas Industry
Authors: Haroon Sarblund , Viswanathan Aruna , Shenoy Ramachandra 
Published: November 2018

Abstract
We are in an era where digital technologies are developing at exponential rates and transforming industries wholesale. The confluence of machine learning advances, accelerated growth in acquired data, on-demand CPU and GPU driven computing such as cloud infrastructure, and other advances in automation and robotics are causing an industrial revolution that some term as the "Fourth Industrial Revolution". Given that all these transformative technologies are now available and rapidly reinventing other industries, why is the rate of adoption in the oil and gas industry so slow? How can we best utilize these advances to stop drowning in data and instead transform this data into information and knowledge in order to enable secure and intelligent automation in oilfield operations?
The oil and gas industry has attempted, at times successfully, a multitude of big data and analytical techniques to further describe and analyze the systems’ or system of systems’ subsurface interactions. While the proofs of concepts have shown promise, structural difficulties embedded in the design of 20th century systems hinder the implementation of the methods and procedures now part and parcel of the 21st century, driven forth because of the Fourth Industrial Revolution. Unfortunately, 20th century procedures are not able to incorporate 21st century driven processes and methods of conducting business.
We outline some of the structural challenges facing the oil and gas industry and describe a few of the solutions that have been developed to help companies in the industry. These include applications from the subsurface in geophysics, completions design, and production. Overcoming data silos in traditional data infrastructure requires a novel approach to cloud infrastructure that respects user access, data privacy, and data residency requirements of companies. Assessing data for quality and for reasonable diversity and variation in order to answer questions posed by oil & gas companies can be quite profound. This critical step prevents companies from spending lots of non-productive time and money trying to develop and tune machine learning algorithms to produce answers that are simply not available in the data. Further, getting data to be in a form suitable to apply artificial intelligence can be quite involved.
We illustrate the above challenges by several subsurface examples and then describe the implementation of novel solutions. What we will show is that the oil and gas digital highway presently has data traffic jams preventing it from moving at the speed of light. Removing these traffic jams offers decision-makers the opportunity to move from insight to foresight – looking out in front instead of the rearview mirror to drive change.
Finding the Optimal Horizontal Well Trajectory using Monte Carlo Techniques: Implementation Details and Case Study in Abu Dhabi, UAE
Authors: Arroyo Negrete Elkin , Webb Steve , Rodriguez Jose , Mavromatidis Angelos , Al Blooshi Ahmed , Basioni Mahmoud 
Published: November 2018

Abstract
Optimal field development plans are often required to maximize reservoir recovery while keeping costs low. This paper discuss the details of how to select the optimal horizontal well trajectory that maximizes reservoir recovery for an interbedded thinly layered carbonate reservoir. The case study here was applied to one of the largest wet gas / gas condensate fields in the UAE. The development plan targets four different reservoirs using horizontal wells. Each reservoir has different rock qualities, and the top reservoir is not in communication with the three reservoirs below.
Each reservoir contains 3-4 sub-layers with varying reservoir properties. Some of the sub-layers may not be in communication with the others, and the vertical communication could be poor. In order to maximize recovery, the development plan calls for placing the horizontal wells crossing from one sub-layer to another sub-layer. The problem is in deciding how long the horizontal well should stay in each sub-layer. Since there are four reservoirs and an average of three sub-layers per reservoir, there are twelve possible lateral placement options that control the well trajectory and length. The methodology presented in this paper utilizes Monte Carlo sampling to calculate the well trajectory that maximizes recovery. The methodology resembles the ideas of the Metropolis Algorithm used in the Marko Chain Monte Carlo. The starting point uses an arbitrary well trajectory. This well trajectory is run in the simulator, and the cumulative production is saved as a reference. Subsequently, the same distribution is sampled and the simulator is run again. If the resulting recovery is greater than the initial recovery or the recovery from any prior iteration step, then the newly found well trajectory is used as the new mean of the distribution, and the steps are repeated until simulated field recovery does not substantially increase.
Novel Application of Coriolis Meters in Custody Transfer Applications
Authors: Rajendran Arivazhagan 
Published: November 2018

Abstract
This paper describes the novel application of Coriolis Meters in custody transfer applications related to ADNOC Gas Processing sales gas network. Though Ultrasonic meters are the preferred choice for custody transfer applications, Coriolis meters are widely used for similar applications in smaller pipelines due to its accuracy and turndown ratio as well as less Operational Expenditures.
Coriolis flow meters operate based on the Coriolis principle invented by Gaspard Gustave de Coriolis over 180 years ago. The Coriolis meter directly measures mass flow. It consists of a tube that oscillates at its resonance frequency. If the tube is empty, it will oscillate uniformly but if it is not empty, twisting of the tube will be observed resulting in phase shift between the two ends of the tube which is directly proportional to the flow. Also, this technology can be utilized to simultaneously measure the density as the oscillation is inversely proportional to the density.
Even though turbine and positive displacement meters are suitable for custody transfer applications, Coriolis flow meters are preferred as they do not have moving parts. Coriolis meters provide increased accuracy because of its ability to directly measure mass flow without the requirement for temperature and pressure compensation. It is not affected by the flow profile, thus does not require upstream and downstream straight length requirements. In addition, it is reliable, fast and has diagnostic features as well as dynamic responses which make it fully suitable for custody transfer metering.
Although the associated Capital Expenditures are high, for lower line sizes (6" size and less), their Operational Expenditures are relatively low, resulting in lower total cost of ownership.
Coriolis flow meters are conventionally used for liquid applications. For gas custody transfer applications, ultrasonic meters are predominantly recommended for larger pipe line sizes. However, for lower line sizes (6" size and less), ADNOC Gas Processing follows AGA (Report No. 11: Measurement of Gas by Coriolis Meter, approved by API for Custody Transfer Applications of Gas) standard to implement the technology in custody transfer metering applications for sales gas, and it has been found to be successful.
From Sand Production to Oil Recovery Through the Unusual 3 ¾-in. TTRD Application on Gullfaks Field, North-Sea
Authors: Khalil Haitham , Labrousse Sebastien , Caycedo Alberto , Moldekleiv Rune , Downie Simon , Esmat Mohamed , Færevåg Vidar , Kristian Andersen Stein 
Published: November 2018

Abstract
Drilling a re-entry well is a routine operation on mature fields. Several techniques are generally used for re-entry operations including cement plug sidetrack and whipstock sidetrack (Hussain et al. 2016). Often the completion string is pulled prior to performing the sidetrack operation but when it is not, one calls this operation a Through Tubing Rotary Drilling (TTRD). Benefits of TTRD wells include lower cost to access small hydrocarbon reserves.
Through-tubing wells are usually drilled with small hole sizes and in Norway such wells are generally drilled with 5 7/8-in. or 5 ¾-in. hole sizes. In this paper we present the case of a through-tubing well drilled with an uncommon 3 ¾-in. hole size.
This paper will: Present the reason for planning such a sidetrack: drilling 3 ¾-in. hole is a rare operation on the Norwegian Continental Shelf (NCS)Describe the solution selected for the operation, including the directional plan, the whipstock setting operation and the 3 ¾-in. bottom hole assemblySummarize the risks and compensating measures associated with this solution, including the low buckling margins in this well planned at inclinations higher than 90°, the low tolerances on the downhole connections that could lead to a twist-off, the limited experience with the directional behaviour of such a slim bottom hole assembly, the bit design.Present the results of the successful operation: this rare 3 ¾-in. hole drilled on the Norwegian Continental Shelf was drilled successfully and below budget.Find the main drivers that will make this solution portable to other situations
This case study demonstrates how detailed and thorough planning based on modelling led to the successful delivery of a rare well design at first attempt. It is an objective of this paper to share some key elements that will be useful for the planning of similar operations in other wells in the future.
Technology Demonstration Journey in ADNOC R&D – A Case Study
Authors: Khan Ibrahim M , Al Wahedi Yasser , Balasubramanian Vaithilingam , Tsapatsis Michael , Geuzobroek Frank , Saif Al Nasr Adel , Al Daghar Khadija 
Published: November 2018

Abstract
This paper explains the process work flow steps starting from the proof of concept of a new research technology up to the field demonstration considering a live example. We discuss the stages that are employed in ADNOC R&TD technology management process in assessing proposals, supervising projects progress, steering projects towards technology maturity. The example under study pertains to a research project which was awarded to Khalifa University (KU). The project attempts at solving high SO2 emissions from old Sulfur Recovery Units (SRUs) in ADNOC Gas Processing. The subject project is research work involving development of a mixed metal oxide, highly selective regenerable adsorbent possessing high adsorption capacity of 6 to 8 mmol/g. We follow the progress of the new technology via the various steps of ADNOC R&D technology management process.