bluuebunny/crossref_metadata_2025_split huggingface dataset:
Installing Highly Alloyed Corrosion-Resistant Alloy 25% Chrome Tubing with Dope-Free Connections in Triple Joint Stands to Reduce Running in Hole Time in an Offshore Field
Authors: Bertoldi L. G. , Goretta E. Actis , Piemontese M.. , Sita F. J. , Joao O. C. , Okolie E. V. 
Published: November 2020

Abstract
This paper describes the novel experience of running Corrosion-Resistant Alloy (CRA) 25% chrome tubing with Dope-free connections in triple joint stands to reduce online running-in-hole (RIH) time. To achieve this, an international operator of a deepwater field development in Angola, defined a special set-up for the make-up and handling equipment, along with connections featuring Dope-free technology.
5 V2" production tubing strings were run in triple joint stands in 2 deep water wells offshore Angola. Well "A" had 14 triples while Well "B" had 67 triples installed. Running highly alloyed CRA tubing with Dope-free technology in stands, in conjunction with using the special handling equipment resulted in faster and safer installations, thus reducing operational risk and saving rig time for the operator. Furthermore, the thread compensator performed the make-up with the neutral point at thread pin thus minimizing stress at the thread's metal seal zone. Several other benefits recorded include savings in jet-wash water, zero dope discharge, reduced personnel exposure to risk, reusability of non-contaminated thread protectors and improved well productivity.
The notion of installing highly alloyed CRA tubular in oil and gas wells initially considered too sensitive to be run in triples has been shown to be conservative. This paper shows that from field experience, running highly alloyed CRA tubulars with Dope-free connections in triples is achievable with demonstrable operational improvement and increased reliability.
The Enhancement of Horizontal Water Injection Well by Integrating Single Well With Full Field Dynamic Model in Carbonate Reservoir: Case Study from North Kuwait
Authors: Ashawesh Luai , Al-Otaibi Basel , Khoriakov Vitaly 
Published: November 2020

Abstract
Water injection using horizontal wells has started since 2012 in North Kuwait carbonate reservoirs. The objective of this work is to integrate a detailed steady-state single well model with a dynamic reservoir model along to improve the permeability distribution inside the dynamic model along the horizontal section of the well.
The workflow starts first by building a well model and quantifying the injectivity profile along the horizontal section from the actual wellhead injection pressure and dynamic reservoir parameters. Then the ILT (Injection Logging Tool) data is used by the well modeling simulator to calculate permeability distribution along the horizontal section of the well resulting in the measured outflow profile. The final step is to export the permeability multipliers along the open hole horizontal section of the well into the dynamic model to improve the dynamic model results at the well level.
This workflow was examined on one injection well from the North Kuwait Carbonate formation and shows improvement in well bottom hole injection pressure, reservoir pressure, well injectivity index and water injection rates distribution along the horizontal Openhole section from the dynamic model and better history match.
The coupling of a single-well advanced ILT interpretation with the field-scale dynamic model is considered as a novel approach that improves the dynamic modeling construction on a well-scale level. Instead of a classical approach where reservoir properties are used only to calculate outflow into the well an inverse problem is solved: calculate reservoir properties from a measured outflow profile.
Operational Challenges of Hydraulic Fracturing of Thin, Low Permeability and Highly Sour Reservoirs in the UAE – A NOC Journey
Authors: Edmonstone Graham , Martin Anthony N. , Turniyazov Nurlan , Talib Noor , Al Shehhi Hessa , Jaiyeola Abiodun , El Shahat Ayman , Gerardo Cardozo Luis 
Published: November 2020

Abstract
Although hydraulic fracturing is widely employed throughout most of the Middle East Region's carbonate reservoirs, it remains a relatively unused improved oil recovery (IOR) technique within the Emirate. Given the Company's goal to increase gas production, an in-country initiative was mandated to progress hydraulic fracturing of low permeability reservoirs. A multi-disciplinary project team was created and tasked to prove that hydraulic fracturing of a single horizontal lateral would give an improvement in well performance and value to that of the current technique of drilling open hole tri-laterals.
The first step of the project to develop fracturing capability and best practices, required detailed up front planning by drilling a vertical pilot hole to collect data to build the mechanical earth model (MEM) and thus improve the fracture modeling and design.
The challenges faced in the project so far were:
Data sourcing, calibration and modelling. Low permeability sour gas reservoir with H2S and CO2 around 7%. Gross reservoir thickness less than 50ft. and the absence of strong mechanical barriers to adjacent depleted reservoirs. Limited experience of hydraulic fracturing and conducting operations with a drilling rig. Zonal isolation for open hole multi-zone hydraulic fracturing in low permeability reservoirs. Technical and commercial processes for sourcing required equipment and optimising job execution.
This paper will outline the strategies and tactics employed to implement fracturing in low permeability, thin, sour gas reservoirs, as well as the technical, operational, logistical and contractual challenges that have had to be overcome to date. The stated challenges and also that of operating under current restrictions due to global virus conditions will be described. The contents of the paper and subsequent material will build a Best Practice to successfully implement hydraulic fracturing operations in the Emirate.
Managing Offshore Deepwater Decommissioning: Subsea and FPSO Decommissioning and Abandonment in West Africa
Authors: Zainal Abidin Suzaini 
Published: November 2020

Abstract
An oil field located about 80km west of the African coast at the water depth of 818m had reached its end of economic life. The facilities and wells would need to be decommissioned and abandoned (D&A). The Floating Production Storage & Offloading (FPSO), which was the key component of the facilities, would need to undergo the disconnection and demobilization (D&D) phase. The objective of this campaign was to restore the field back to its safe condition whilst minimising the environmental impact, complying with local and international legislative. The abandonment & decommissioning works was performed in line with good industry decommissioning practices at the most optimize cost. Upon completion of the D&D, the FPSO would need to be demobilised to her original base in the South East Asia (SEA).
This paper discusses a case study for a D&D campaign and activities of the FPSO which includes the Subsea, Umbilical, Riser and Flowline (SURF) and mooring system. One of the crucial areas during the execution phase was pertinent to the management and disposal of the hazardous waste that is subjected to transboundary movement as per the relevant convention. Amongst the hazardous waste were Natural Radioactive Occurrence Material (NORM), low specific activity (LSA) material, hydrocarbon sludge and contaminated water. The FPSO need to be cleared from the above said hazardous waste for her to be accepted by the receiving base country.
This paper also describes the actual experiences and lessons learnt which can be applied for future projects.
Applied Cognitive Cleaning Technology to Increase Average Heat Transfer Coefficient of Heat Exchangers
Authors: Rodin Ilya , Cherednik Eduard , Dolbunov Alexey 
Published: November 2020

AbstractIndustrial processing such as crude oil refining, petrochemical production, power generation and other may involve the transport of hot and cold utilities (fluids or gases) through heat transfer equipment such as heat exchangers. Over time and under various conditions, this transport of such utilities may result in fouling and scale deposits forming within the preheat trains or heat exchangers. Fouling and scale deposits reduce the performance of the equipment, leading to heat energy losses which has a negative productivity impact as well as overall negative economic and environmental impact on the industrial process.Due to the lack of existing technologies oil refineries clean their key heat transfer equipment during major overhauls or roughly once in 2-4 years. Between these stops heat exchangers work below 50% of their heat transfer efficiency.Cognitive Cleaning systems and methods integrates chemical innovation, process innovation and business model innovation into a single solution aimed to maximize technical, economic and environmental performance of the industrial processes through reducing energy intensity of the processes via cleanliness of heat exchangers.Cognitive Cleaning is applicable for wide range of equipment geometry: shell and tube, plate, spiral heat exchangers. According to laboratory tests and on-site implementation's it is safe for equipment and has no harmful residues after cleaning.Cognitive Cleaning technology was successfully commercialized on operating bitumen units, CDU, VDU, acid alkylation unit; on spiral, plate, shell-and-tube heat exchangers of several refineries of Gazpromneft, LUKOIL, TANECO demonstrated boost in equipment efficiency. Companies were able to extract real value out of previously done investments into digital infrastructure.Applied cognitive cleaning can keep cleanliness of equipment increasing heat transfer efficiency up to 70%-80%, reduce CO2 emission and return around $2.4B to oil refineries of GCC countries.
Analysis of Surface and Downhole Drilling Dynamics High-Frequency Measurements Enhances the Prediction of Downhole Drilling Dysfunctions and Improves Drilling Efficiency
Authors: Jones Steve , Sugiura Junichi 
Published: November 2020

Abstract
Drilling rigs in North America are outfitted with Electronic Data Recorder (EDR) systems that acquire measurements from rig sensors. These systems typically record surface data at low frequency (0.1-1Hz) which makes it difficult to identify high-frequency events that could be occurring downhole. In an effort to fully understand the transmission characteristics of drilling dynamics signals along the drill string, the top-drive saver sub was embedded with high-frequency drilling dynamics sensors, sampled and continuously recorded at either 800Hz or 1600Hz.
Instrumenting the bit, bottom-hole assembly (BHA) and surface saver sub with identical high-frequency drilling dynamics sensors provided a unique insight into drilling dynamics transmission along the drill string. The sensors were identical and outfitted with the same hardware, firmware and software to allow detailed dynamics signal analysis to be undertaken. The signals from the high-frequency surface and downhole sensors were combined with the low-frequency surface rig measurements for pattern recognition and correlation analysis.
All high-frequency surface/downhole drilling dynamics data and low-frequency EDR data were merged and over-laid to identify signal patterns that would be beneficial in understanding surface and downhole generated dysfunction. Vertical, nudge, tangent, curve and lateral sections of the wellbore were analyzed to fully understand the transmission of drilling dynamics from downhole to surface and from surface to downhole. It is discovered that at relatively shallow depths, the signatures of at-bit dysfunction were observed in the high-frequency lateral vibration channels. Even in deeper wells, certain rotation-speed and shock/vibration signatures were detected at the surface.
The novelty of identical high-frequency drilling dynamics sensors at surface and downhole is that the signals generated by each sensor are produced from the same hardware, firmware and software. There is no risk of signals being mis-interpreted because of the use of different sensors or different signal-processing methods downhole and on surface. Merging and overlaying of the signal data with rig EDR allows drilling dynamics patterns to be correlated.
First Hydrocarbon Discovery in Thin Clastic Reservoir in Western UAE by Applying Innovative Data Integration Solution
Authors: Aftab Muhammad , Sultan Mir , Swain Ashis , Al Blooshi Abdulla , Gareyshin Radik , Mingsheng LV , Abdalla Ruaa 
Published: November 2020

AbstractExploration is a high risk business. Hence, available data including those from offset fields have to be analyzed and reviewed critically prior to drilling a well. This becomes especially true in a marginal thin reservoir where innovative drilling and testing strategy would play a key role in deciding commercial discovery of the prospect.Flow rate is one of the basic criteria, inter alia, on which commercial viability of a prospect depends. Conventional testing strategy performed in the vertical well did not yield commercially viable flow rate. Hence, innovative approach was adopted to achieve the desired results.After drilling, multi-disciplinary data should be integrated to finalize the testing strategy, which is critical to announce the discovery to meet the criteria set by the company. Reservoir of interest is a thin clastic reservoir, which could not meet the criteria of flow rate during testing with conventional way even though volume in place assumed to be significant due to large area. After carefully reviewing all data, the flow rates were predicted with the modeling if well will be horizonalized.In order to fully evaluate the prospect, the static and dynamic model of the first vertical well was thoroughly reviewed and re-evaluated. The vertical well was tested comingled with two reservoirs having a two feet dense layer between the two. The well flowed mostly water with traces of oil. A detailed review of the test data revealed that a higher prospectivity layer exists in the overlying thin clastic reservoir above the dense and that the two reservoirs are in isolation. Based on this finding, a modeling was performed to decipher optimal horizontal well length to achieve the flow rate. It was a challenge to geo-steer the well trajectory of horizontal section in this very thin reservoir, which was successfully achieved by an active coordination of an integrated teamwork.An innovative approach was adopted by applying Wireline Formation Tester (WFT) data to confirm dynamic isolation from underlying reservoir, which is predicted to be major water contributor. Optimal horizontal well length was established by analytical model for achieving the best flow rate.The well was drilled successfully with horizontal length of 1400 ft. in thin clastic reservoir and completed with fit-for-purpose completion followed by production testing that achieved the flow rate criteria as predicted in the model.This paper summarizes the processes of: (1) data integration, (2) establishing reservoir segmentation based on static and dynamic data, (3) modeling to predict flow rate and optimal horizontal length, (4) selection of fit-for-purpose completion and (5) addressing challenges and lessons learnt during planning and execution phases.
A Novel Approach, Determining Oil Pockets Size in a Very Complex Combination of Structural and Stratigraphic Traps of Middle Cretaceous Formation in Onshore Abu Dhabi
Authors: Jaya Sangga , Al Menhali Helal , Al shkeili Fatema , Shashanka Ashis 
Published: November 2020

AbstractMishrif formation has complex combination of stratigraphic and structure traps in western part of Onshore Abu Dhabi where according on petroleum system in western onshore Abu Dhabi there are three formations play roles; Shilaif formation acts as source rock, Mishrif as reservoir and Tuwayil seal as seal. Historically during the past decades less commercial discoveries have been thriven in Mishrif formation.Generally, Mishrif formation consists of three Units: a lower Unit composed of fine-grained bioclastic packstones and wackestones, which represent distal shelf slope environment. The middle unit consists of medium-grained packstones indicative of proximal shelf slope environment. The upper Unit consists of coarse-grained bioclastic and shelly packstones and grainstones (rudist shell and debris) indicative of shoal of environment. Mishrif shoals are the favorable area where hydrocarbon charging was controlled by the heterogeneity inside shoal which has good reservoir qualities in term of porosity, permeability and oil saturation.This case study is unique where the marginal field has several Mishrif reservoir pockets due to combination traps; stratigraphic and structural traps where lateral facies heterogeneity also plays a crucial part.Several wells have been drilled and tested in Mishrif Formation during 1970's however the result still not encouraging and the company recently drilled appraisal wells; two vertical and one long horizontal well has been drilled towards an existing well and interference well test been implemented. Comprehensive data integrations of G&G and Reservoir Engineering are incorporated to generate/build new subsurface understanding with numerous geological concepts and several analog fields have been considered in order to generate new understanding.
ADNOC Senior Women's Leadership Development
Authors: Coffey Elizabeth 
Published: November 2020

Abstract

Objectives
Our aim was to prepare senior women in ADNOC for progression through Accelerated Leadership Development:∘to progress one or more into CEO roles by 2020∘to build the pipeline of the top 75 senior women leaders, priming their advancement within the organisation and∘to change leadership culture in ADNOC to be more inclusive and leverage diversity of both female and male leadership styles

Methods
Between November 2017 and June 2019, we deployed 3 strands of development:∘Accelerated Leadership Coaching for senior female leaders▪Each was coached 4 hours a month for 6 months∘6 Leadership Workshops for the top 75 female leaders, covering competencies critical for success in ADNOC's CEO and Director level.▪Strategic Influencing, Leading Change, Gravitas, Leadership Priorities, Managing Conflict, Making an Impact in Senior Groups∘Mentoring Workshops for the Group's 20 most senior men (CEO and Director level roles) and women.▪Content included gender differences in leadership styles.▪Mentoring pairs met monthly over 6-months.

Results

Novel information
Digital Transformation of Historical Data for Advanced Predictive Maintenance
Authors: Giunta Giuseppe , Bernasconi Giancarlo , Giro Riccardo Angelo , Cesari Simone 
Published: November 2020

Abstract
In recent years, big data technologies have paved the way for digital transformation in oil and gas industry. Multi-domain measurements are collected by advanced sensor systems and processed using data-driven approaches, allowing to derive constitutive relations between the operational status of the asset and the measured variables. In addition, historical pressure measurements can be exploited for advanced pipeline monitoring. This paper presents a methodology, applied to a case history, where legacy data are repurposed and employed both to track pump health and to enhance the digital conversion. The dataset consists of past pressure signals collected by Eni for several years at the pumping terminal of a crude oil transportation pipeline, which has a length of 100 km and 16" diameter pipes, located in Italy. Pressure transients' variance, kurtosis and variation range, computed on appropriate window lengths, are fed to an unsupervised clustering procedure based on a Gaussian Mixture Model (GMM), which automatically identifies four clusters. An expert analysis of the labeled data reveals that each cluster corresponds to a well-defined and different pump operational mode, namely: standby (pumps off), transition (pumps switching on/off), normal (line flowing) and anomalous. The latter mode is connected to a high value in the pressure transients' variance and kurtosis: during such regime, pump maintenance logs report a failure and replacement of a system part. Interestingly, the anomalous condition starts to show up several days before the actual part replacement. The proposed case history reveals the potentiality of: adding value to legacy data, as they can be reprocessed, tagged and used as supervised examples in the training phase of new data-driven procedures; comparing, merging and complementing monitoring strategies of assets at different digitalization stages; aiding the development of predictive maintenance strategies.
Mature Fields - Optimizing Waterflood Management Through DNA Based Diagnostics
Authors: Sawadogo Jordan , Ursell Luke , Reeve Nicolai , Schlecht Mathias 
Published: November 2020

AbstractMaximizing the recovery factor achieved through water flooding depends on acquiring a detailed understanding of the vertical and areal sweep efficiency. DNA diagnostics can monitor changes in oil contributions from multiple zones and from injectors, becoming a leading indicator for the potential of water breakthrough, loss of injectivity, and the overall advancement of the water front when combined with subsurface information. This allows for proactive management of injection rates and timing to maximize recovery rates for green fields and brownfields alike.DNA diagnostics use DNA markers acquired from microbes. DNA markers of produced fluids are compared to the DNA markers of injected fluids to establish relationships and shared fluid flow. This paper will cover the end to end workflow for long term waterflood monitoring:Establishing end members, even for a mature field, with the use of new samples from offset wells, properly stored samples from existing wells, and the analysis of commingled samples in combination with the subsurface model.Establishing the level of similarity between injectors and producers as an indication for the progression of the waterflood front using methods including Principal Coordinate Analysis (PCoA) of DNA marker profiles.Performing time series analysis and establishing sampling periodicity for effective waterflood monitoring.A pilot project, consisting of 12 producers and 3 injectors in a conventional California reservoir, was conducted to prove the concepts and further develop the required analysis for waterflood monitoring. Fluid samples were taken weekly on each well over 3 weeks to establish the difference in DNA markers between the fluids. The DNA markers were used to determine the probability that injection fluid was being produced from the surrounding wells. These results were overlaid to temporal changes in the Total Fluid Logs. Taken together, the results correlated and confirmed previous water breakthrough information and provided insights into arial and vertical conformance changes. Additionally, the project provided new insights into strength of producer and injector connection based on geological features and with that informing future infill drilling decisions.Waterflood monitoring is a powerful application for DNA diagnostics that is deployable on new and existing waterfloods. The spatial and temporal monitoring limitations of modeling or tracer studies can be improved upon through this non-invasive diagnostic. Initial results demonstrate the insights that can be provided not just for monitoring the waterflood but also for further field development decisions.