bluuebunny/crossref_metadata_2025_split huggingface dataset:
Single-Trip Completions Made Simple with a New, Field-Proven Valve Technology
Authors: Dikshit Ashutosh , Woiceshyn Glenn , Kumar Amrendra 
Published: November 2020

Abstract
Interest is high to reliably run single-trip completions without involving complex/expensive technologies. The reward: significantly reduced rig time and completion costs. As described herein, a unique pressure-activated sliding side door (PSSD) valve was developed and field-tested to open without intervention after completion is circulated to TD and liner hanger and open-hole isolation packers are set. A field-proven sliding-sleeve valve that required shifting via a shifting tool run on coil tubing, slickline or wire-line, was upgraded to open automatically after relieving tubing pressure once packers (and/or liner hanger) are set. This PSSD technology, which is integrable to any type of sand control screen, is equipped with back-up contingency should the primary mechanism fail to open. Once opened, the installed PSSDs can be shifted mechanically with unlimited frequency. The two-or three-position valve can be integrated with ICDs (includes AICDs/AICVs) and allows mechanical shifting at any time after installation to close, stimulate or adjust ICD settings.
After a computer-aided design stage to achieve all the operational/mechanical requirements, prototypes were built and tested, followed by several field installations. The design stage provided some challenges even though the pressure-activation feature was being added to a mature/proven SSD technology. Prototype testing in a full-scale vertical test well proved invaluable as it revealed failure mode that could not have appeared in the smaller-scale lab test facilities. Lessons learned from the first field trial helped improve onsite handling procedures. PLT logs run on first installation confirmed the PSSDs with ICDs opened as designed. The second field installation involved a different size and configuration, where PSSDs with ICDs performed as designed. The unique two-or three-position PSSD accommodates any type of sand control or debris screen and any type of ICD for production/injection, which can be easily adjusted at the wellsite. The scope of application is extremely broad. Consequently, more wells that normally could not justify the expense of existing single-trip completion technologies can now benefit from the enormous cost savings of single-trip completions, including ones that require ICD and stimulation options.
Wireline Conveyed Robotic Intervention for Obstruction Cleaning and Sampling in Horizontal Wells Completed with Open Hole – Worldwide First Job Experience
Authors: Yakovlev Timofey , Sagr Hani , Al Harthi Sultan , Aulia Fahmi 
Published: November 2020

Abstract
The objective of this paper is to share the experience of first worldwide job where wireline conveyed robotic cleaning tool was utilized to clean the obstruction in open hole section of oil well while collecting of uncontaminated sample of blockage material.
Wireline conveyed, lightweight, robotic intervention tools were used in one of fields in Saudi Arabia to collect uncontaminated sample of obstructive material for future chemical treatment and to remove the bridge in Open Hole section of oil well, so Workover Rig or Coiled Tubing intervention can be avoided or significantly deferred. Operation was performed without killing the well and with no additional fluids pumped into well, reducing possible intrusion and skin build up. This technology was run first time in world practice to clear an obstruction in Open hole section.
Severe planning was performed prior to technology introduction, including possible solutions comparisons and risk assessment. Robotic intervention was proven not only technically superior, but yielded large economic benefits compared to traditional descaling and sampling methods. It involved less personnel and produced much less CO2 footprint as well.
Sample retrieved during the operation was analysed in laboratory and with high degree of certainty can be attributed as localized formation collapse. Same was confirmed by limited length of blockage that was successfully removed. This represented additional mechanism of wellbore restriction in the field.
The experience from first worldwide operation, the methods and tools descriptions, process, lessons learned, recommendations and way forward will be presented in this work and should be of great interest for wide group of practicing engineers.
Data Driven and AI Methods to Enhance Collaborative Well Planning and Drilling Risk Prediction
Authors: Mohan Richard , Hussein Ahmad , Mawlod Arwa , Al Jaberi Bashaer , Vesselinov Velizar , Salam Fouad Abdul , Al Hadidy Khaled , Pal Anik , Al Yazeedi Haifa , Al Daghar Khadija , Mustapha Hussein , Razouki Ali , Al Hamlawi Imad , El Yossef Bassem 
Published: November 2020

Abstract
ADNOC is continuously enhancing its capabilities to manage its oil and fields efficiently by better planning, execution and operations that drives field development decisions, well performance, and safe operations. In this regard, ADNOC envisages to leverage the evolving Oil and Gas 4.0 technologies to enhance the well planning decisions of the sub-surface and drilling team through data-driven and AI methods.
Effective well planning and operations require collaboration between different subsurface teams and drilling team leveraging multidisciplinary data, historical events and risks and constructing integrated drilling and sub-surface model for collaborative planning and keeping the model live. This requires having a live sub-surface model that is kept close to the field reality while reducing uncertainties. However, extracting key learnings, knowledge and experience from a variety of sources and reports is intense and requires lot of manual processing of data.
An AI-based solution leveraging data analytics, natural language processing and machine learning algorithms is developed to automatically extract knowledge from a variety of data sources and unstructured data in building a live intelligent model that enables effective well planning, predicting operational hazards and plan mitigation. The solution systematically extracts, collects, validates, integrates, and processes a variety of data in different formats such as well trajectory, completion, historical events, risk offset well information, petrophysical data, geo-mechanical data, and technical reports. Newly acquired data comprising drilling events, geological and reservoir properties are integrated continuously to keep the model live and digital representation.
First Successful Fishbone Stimulation Completion in Onshore Oil Field in the United Arab Emirates.
Authors: Quintero Fernando , Talib Noor , Jimenez Alvaro , Chehabi Wissam , Ramarao Subba , Al Nuami Mouza Ali , Al Reyami Mazin , Hapa Cankat , Rodriguez Edward 
Published: November 2020

Abstract
Fishbone Stimulation Technology was developed to increase the well productivity from the tight reservoir for maximum hydrocarbon recovery. Additionally, this technology was implemented in a thin reservoir where conventional stimulation techniques have not been effective and very risky for more aggressive stimulation technique such as hydraulic fracturing.
The application of Fishbone Stimulation Technology was the first time experience representing a massive uncertainity. Thus, a multidisplinary team was estasblished, including members of different departments of the operator and contractors, to design the operational procedures, conduct risk assessment, contingency plans, technical requirements and technical limitations. this first implementation of the fishbone stimulation in ADNOC Onshore served as the benchmark and reference for other fishbone candidate wells in ADNOC Onshore and other ADNOC subsidiaries.
The deployment of the equipment and the production results were a complete success overcoming the risks and previously mentioned uncertainities, closing some gaps from previous partial effective applications in other companies.
The Fishbone stimulation technology will help to increase the well productivity via below mechanism in a well that is too risky to be hydraulically fractured and beyond the coiled tubing reach:
Extension of the needles to connect natural fractures and vertical layers (for reservoir with poor Kv/Kh) Increase reservoir contact Sweep Efficiency of the reservoir
Stress-Dependent Petrophysical Properties of High Heterogeneous Carbonate Tight Oil Reservoirs
Authors: Al-Ameri Nagham Jasim , Hamd-Allah Sameera Mohammed , Abass Hazim Hussain 
Published: November 2020

Abstract
As a reservoir is depleted due to production, pore pressure decreases leading to increased effective stress which causes a reduction in permeability, porosity, and possible pore collapse or compaction. Permeability is a key factor in tight reservoir development; therefore, understanding the loss of permeability in these reservoirs due to depletion is vital for effective reservoir management. The paper presents a case history on a tight carbonate reservoir in Iraq which demonstrates the behavior of rock permeability and porosity as a function of increasing effective stress simulating a depleting mode over given production time.
The experimental results show unique models for the decline of permeability and porosity as function effective stress. This stress sensitivity is even more pronounced in cores with lower initial porosity and permeability. The pores’ size and shape, as well as mineral content provide important reasons for various functions in the stress-dependent behavior of the porous media. Additionally, mercury injection capillary pressure (MICP), thin section (TS) results, scanning electron microscope (SEM) data, and X-Ray diffraction (XRD) are incorporated to relate the microscopic controlling factor to stress sensitivity behavior of this reservoir formation.
The results indicate that permeability is more sensitive to effective stress than the porosity. Different responses to the stress of similar initial permeability are discussed according to their mean hydraulic radius (MHR). Distinguished fabric signatures for the studied reservoir is identified from grouping the MHR-permeability relations, which is significant and can provide insight on the heterogeneity of a given reservoir and how it is related to pore size distribution. This grouping mode provided better data allocation than depending on other parameters such as; conventional samples’ initial petrophysical properties, pore size distribution, MHR values, reservoir stratigraphic units division, and clay content for the samples, which all failed in achieving reasonable data grouping for the tight reservoir under study. A relation of the viscous behavior (ductility/brittleness) of this tight reservoir to permeability and stress is examined.
IT/OT Convergence – Cybersecurity Beyond Technology
Authors: Paredes Ignacio 
Published: November 2020

Abstract
When the first PCs were deployed in industrial automation environments during the 1980s, it was difficult to imagine how the information technology (IT) would influence the day to day operations of industrial organizations. For the last decade or so, the convergence of operational technology (OT) and information technology has been an important topic in organizations whose operations rely on industrial control systems.
The advantages of the IT/OT convergence are obvious – cost reduction, improved capabilities or greater efficiency. However, these advantages come with a cost as they have affected the way that industrial control systems operate and increased the exposure of ICS to cyber risks.
According to one research study, nearly 90% of organizations with connected OT infrastructures have experienced a security breach within their Supervisory Control and Data Acquisition and Industrial Control Systems (SCADA/ICS) architectures, with more than half of those breaches occurring in just the previous 12 months.
Minimizing Erosion of Downhole Proppant Flowback Control Equipment During Fracturing
Authors: Woiceshyn Glenn , Dikshit Ashutosh , Agnihotri Vivek , Chochua Gocha , Noor Mohd Nazri 
Published: November 2020

Abstract
Proppant flowback from hydraulic fracturing is widespread and costly due to erosion and/or blockage of producing hydrocarbons due to proppant accumulation. One remedy is to install sand control equipment integrated into a sliding sleeve device (SSD) as part of the completion string, which raises concern about erosion during fracturing. While some installations have been successful, at least one experienced sand control failure. Computational Fluid Dynamics (CFD) was deployed to evaluate the root cause and identify more robust designs, as presented herein.
Firstly, we identified the most probable causes of sand control failure during multistage fracturing (MSF) in openhole (OH) horizontals. State-of-the-art CFD simulations were then performed on the installed design using actual flow conditions (rates, slurry properties, treatment time) from a failed installation. The static CFD methodology in an initial undeformed geometry proved to be ultra-conservative, so a new quasi dynamic mesh (QDM) methodology was developed, which yielded more realistic (albeit still conservative) erosion-depth predictions. The results revealed areas for improving the design of key components, and CFD was re-run to confirm erosion resistance targets. The modifications were then implemented for a field trial.
Since frack location between two openhole packers is unknown, and the frack port is located between multiple screen/SSD assemblies, one must consider annular flow across the assembly in both directions. Accurate CFD predictions of erosion of completion components versus time during MSF in OH proved challenging. The quicker static methods were useful in ruling out some components as problem areas, such as the sand control media, but proved overly conservative on other key components. The QDM methodology gave more realistic results and indicated that erosion depths in specific locations could be deep enough to possibly cause sand control failure. To reduce the erosion risk, such components were modified, and the result was a reduction in predicted erosion depths to acceptable levels. A safety factor was already built into the predictions because of two key conservative assumptions: ignored initially were 1) particle-particle interaction and 2) erosion of the reservoir wall. The former was further investigated.
While waiting for the field trial results, the main conclusion thus far is that CFD is a valuable tool for diagnosing erosion failures and improving equipment design. However, it’s essential to use a methodology that realistically captures downhole conditions. Presented herein is a more robust design of a screen/SSD assembly for proppant flowback control, as well as an improved CFD methodology for diagnosing sand control failures during MSF and for identifying design improvements of completion equipment. Furthermore, the inherent challenges of controlling proppant flowback without causing erosion or flow blockage of hydrocarbons are discussed.
First Co-Implementation of Inflow and Inter-Well Tracers in Offshore Abu Dhabi: Towards Cost Efficient Reservoir Monitoring and Management
Authors: Lotfy Mohamed , Loobari Sultan , Samantray Ajay , Al Shekaili Fatema , Al Menhali Helal , ELTahir Bashar , Leung Ed , Huseby Olaf 
Published: November 2020

Abstract
This paper presents the integration of two surveillance technologies, inflow & inter-well tracers in an Abu Dhabi Offshore field, for the first time to monitor a complex multi-layered reservoir with early stage water injection. Inflow tracers are chemicals with unique identities, installed into the lower completions that penetrate different layers in the reservoir. Inter-well tracers are also unique chemicals injected into injection wells. Tracer technologies allow non-electric wireless monitoring of the reservoir for many years while reducing cost and operational efficiency. In both technologies, data capture requires to fluid samples to be collected and analysed to detect the unique tracers in the production wells. Inflow tracers provides both qualitative and quantitative estimates of zonal flow as well identifying the source of water breakthrough. Inter-well tracers introduced in the injection wells can identify the primary flow paths and rate of movement of injected fluid in the reservoir. This information can be used to evaluate water channelling and improve water flood conformance plans to maximize sweep efficiency.
The planning and design stage included a selection of pumpable inter-well tracers, volume calculation and breakthrough time simulations to determine the tracer mass required to meet the monitoring objectives. On the other hand, inflow tracers were designed to account for high temperature and highly acidic stimulation fluids and placed along the producing intervals in the lower completion. Quantification models will be utilized to quantify the zonal influx while accounting for expected cross flow. The execution plan is defined by the optimum production and injection rates, equipment and lab test requirements, and optimized field sampling schedule for transient and steady state flow campaigns.
The co-implementation of both tracer technologies in the early stage of waterflood development offers unique ability to monitor the reservoir, eliminating the need for expensive, complicated offshore logistical arrangements for time-consuming wireline interventions to manage the reservoir more efficiently and maximize recovery.
Smart Digital Asset: Single Source of Truth
Authors: Jadhav Satyaprasad , Qrain Afra Al 
Published: November 2020

Abstract
This presentation describes the efforts undertaken by ADNOC Gas Processing's in standards, procedures and process followed for implementing Smart Digital Asset to optimize the time, efforts and resources required Asset Information Management during Engineering, operation, maintenance, and HSE including following, –Present an information on the concept, features, components, software and applications utilised for Smart Digital Asset.–Outline the scope, methodology, limitations, and results of executing Smart Digital Asset for projects.–Describe the value proposition for enhancing and extending the value chain of company's Smart Digital Asset.
Smart Digital Asset is an innovative web-based zero foot print information search engine that provides a single point access to information anytime, anywhere, and on any device. Its focus on the end users sets it apart from other solutions: "Start with what you know such as tag no's, discipline etc." By having all sources of information in Smart Digital Asset solution in one place ADNOC gas Processing noted following benefits, Improve safety & Asset Integrity.Reduce design cycle time for CAPEX\OPEX Projects by knowing impact of changes to other disciplines, compare data stored in different systems for consistency.Cut down on errors resulting from choosing the wrong set of information. Take information into the field on a tablet.Shorten the repair cycleMinimize facility turnaround and outage time.
Did You Know That Collaborative Thinking Can Lift Your Profits?
Authors: Mukherjee Rahul , Al-Suwaidi Eman , Jabbar Shafiulla , Khoori Ziad 
Published: November 2020

Abstract

Objective / Scope
BOROUGE receives its ethane feedstock (De-Ethaniser Overhead DEO) from ADNOC Gas Processing to produce higher value polymer products. As polymer prices continue to rise, capacity utilization of the crackers is the prime concern for BOROUGE during low feedstock availability from ADNOC Gas Processing.
To maximise profit, propane is slipped along with DEO from ADNOC Gas Processing to BOROUGE and co-cracked to produce higher market value polymer products.

Methods / Procedures
The following activities were carried out to evaluate the feasibility of slipping propane along with DEO.

Results, Observations and Conclusions
During the test run, ADNOC Gas Processing’s Train 4 De-Ethaniser column top temperature was increased from minus -3.5°C to +19.5°C and Propane in Ethane product increased from 0mole % to 6 mole %.
Since fractionation column is a multivariable system, disturbance in any process parameter can affect the overall performance and lead to production loss. Hence, the column temperature profile was increased gradually in multiple steps and sufficient time was given between each step change for system stabilization.
When propane from De-Ethaniser column is slipped, Carbonyl Sulphide (COS) also gets slipped with the DEO stream. Higher level of COS in feedstock to BOROUGE may impact their polypropylene product specification. Hence, frequent lab sampling analysis were carried out by ADNOC Gas Processing as well as BOGOURE to make sure the product quality is not impacted.
The test run was successfully carried out for a duration of more than 80 hours. From the test runs results it was concluded that 15 Tons/hr of propane can be slipped with DEO from ADNOC Gas Processing NGL Fractanation Train 4 to BOROUGE which can be converted to value added polymer products.
Cyber Security Incident Response in the Utility Sector
Authors: Simonovich Leo 
Published: November 2020

Abstract

Executive Summary
Protecting endpoint operating technologies (OT) is an increasingly important challenge for the energy sector. As energy companies continue to digitize existing assets and build new assets with intrinsic network connectivity, they present an ever-expanding attack surface to escalating attacks. Trends show that cyberattacks on OT targets have increased in frequency and sophistication. Meanwhile, structural mismatches in the life cycles and maintenance cycles present a challenging business case for companies seeking to defend assets, rendering current cybersecurity best practices both technically difficult and potentially unaffordable to sustain.
Overall, the energy industry has made tremendous progress in maturing cybersecurity capabilities. Yet current practices leave significant gaps due to lag between updates. Put simply, systems patched on Monday are powerless on Friday to stop attacks methods developed on Tuesday, Wednesday or Thursday.
To meet this challenge and answer both the technical and the business case, future cybersecurity solutions need to meet clear requirements: They must function while isolated, remain potent between updates, provide flexibility for deployment in unique, widely varied OT configurations, and must meet or exceed the cost-benefit ratio of current practices. We believe that artificial intelligence (AI) and machine learning (ML) solutions offer these characteristics, as well as ancillary benefits. This paper will describe in detail the current challenges faced by energy companies, the implications of observable industry trends, the characteristics that potential cybersecurity solutions must meet, and why we believe AI and ML technologies can meet these requirements now and in the future.