bluuebunny/crossref_metadata_2025_split huggingface dataset:
Best Engineering Practices for Asphaltenes Challenges Mitigations at Oil and Gas Production Facilities
Authors: Abbas Zafar , Punnapala Sameer , Abdulla Dalia Salim 
Published: November 2020

Abstract
Asphaltens presence in the reservoir fluid has great implications on downhole as well as surface facilities. These problems are not only related to production impact, but also significant integrity as well as surface facilities operational challenges are seen to affect the upstream oil and gas production facilities. Handling the asphaltenes rich fluid brings inherent challenges with it starting from well bore to the production facilities. Adequate engineering solutions need to be integrated into the design of production facilities as well as wellhead equipment which would greatly enhance production efficiency while successfully facing asphaltens challenges. The nature of asphaltens as well as their growth rate are not very well understood due to their complex chemistry with different hydrocarbons. Therefore there will not be a 100% success while managing the asphaltens, however these proactive steps would upto great extent would reduce the downtime and other asphaltene related impacts.
This paper presents an effective way to address asphaltenes challenges as faced by surface and subsurface facilities in oil and gas production operations. Best industry practices for mitigating asphaltenes related challenges, which not only sustained the production but also enhanced asset integrity performance, have been presented for experience sharing and enhancing the asphaltenes handling capability. The reservoirs with asphaltenes presence are quite difficult to handle and maintain due to complicated nature of asphaltens, which result into various problems with downhole as well as surface facilities. These problems result into scales blockage of well bore and flow lines thus causing blocked flow and in most of the cases complete seizure of wells fluid flow.
Successful Water Shut Off Based on Comprehensive Pre and Post Well Diagnostics
Authors: Skutin Vasilii , Abasher Doha , Izawa Toshihide , Watanabe Kimihiko , Nihei Shotaro , Kuramata Hideaki , Iwasaki Satoshi , Matsuda Hiroki , Nakata Nakata , Alobeidli Abdulla 
Published: November 2020

Abstract
This paper will describe pre and post workover well diagnostic and the successful water shut-off that has resulted. It also talks about the post workover survey. The well was recently completed to a new targeted reservoir and suffered from high water cut (80%) at the start of production. Proper diagnostics identified the source of water and helped in planning a successful remedial job. After water shut off the water cut dropped to zero. Post workover evaluation confirmed production from the targeted interval.
Comprehensive diagnostics are crucial to designing a proper remedial job. A conventional PLT survey will describe the flow characteristics and parameters inside the wellbore only. During the job under consideration, two additional services were deployed; the Spectral Noise Logging and the High Precision Temperature sensing. Their combination with the PLT allows for the assessment of behind casing flow and the identification of active streaks of the formation. The quantification of flow rate behind casing is also achieved by modelling the temperature response from the high precision sensor.
The first survey was conducted with the conventional PLT to identify the source of water. Subsequently, a high precision temperature and spectral noise log were recorded under flowing, transient, and shut-in conditions. A crossflow behind casing from the upper unperforated intervals was identified. The main liquid production is coming from the water-bearing formation that is located 15 ft above the targeted reservoir. The cement evaluation surveys that were run previously confirmed the presence of a cement channel above of the perforated interval. Based on these conclusions a remedial job was designed and conducted successfully. Another HPT/SNL survey was conducted post workover. It confirmed the absence of any further flow behind casing and that all liquid production is happening from the targeted reservoir. Surface test data showed a rapid decrease in water production to 1% post workover.
This paper highlights the importance of complementing the current practice of running conventional PL surveys with two additional services: the Spectral Noise Logging and Temperature simulation/modelling using a High Precision Temperature measurement.
Utilization of Lithium-Ion Batteries in Offshore Platform
Authors: Qaderi S. Al , Wahedi Faisal Al , Ashqar A. Al , Kuwair M. B , Ibrahim G. M , Takieddine Oussama , R. Kamal Faris , Paul Raju , Mazumdar Sumit Kumar 
Published: November 2020

Abstract
This paper explores lithium ion battery as an alternative battery technology and discusses the benefits it can offer to stationary UPS application in offshore platform. A case study on utilization of lithium ion battery in Al Yasat's, Belbazem feed project is presented with an intent to implement in EPC stage and to reduce total cost of ownership.
The paper studies conventional batteries, which are used for the majority of ADNOC offshore platforms. It considers their limitations and surveys alternative battery technologies in different industry sectors. Based on industry trend, market share and technical performance, lithium ion batteries are considered as the preferred candidate. The paper also focuses on different international standards like IFC, IEEE standards for safety and other recommendations.
Conventional batteries due to large size, heavy weight, and low energy density require more space. Additionally, the performance, service life, and total cost of ownership further limit's their usefulness and advantages. Unlike conventional batteries, lithium ion batteries have emerged in recent years as small size, light weight, and high energy density solution which offers significant advantage in terms of footprint and infrastructure cost. This makes lithium ion battery as a potential candidate for offshore platform where space is premium. Under normal condition there is no electrolyte leakage and no outgassing, thus eleminating stringent ventilation requirement, minimizes HVAC energy consumption and contribute to energy optimization. Lithium-ion batteries have long life and very low maintenance requirements. There is no fluid level to measure and maintain. Lithium ion batteries require advanced battery management system (BMS) for their safety. Smart features in BMS offers an array of monitoring capabilities, including system state-of-charge and state of- health which further reduces maintenance burdens. As Lithium ion batteries offers high energy density solution they and are prone to thermal runway. The highest level of safety is ensured with sound material & process control during manufacturing, choice of stable battery chemistry, proper cell & system design and testing in compliance to industry standards.
The proposal to use lithium ion battery for stationary UPS application in ADNOC offshore is novel. It highlights strengths and discusses various aspects of lithium ion batteries which lowers total cost of ownership and ensure safer design in offshore platform. The paper presents various norms currently available in international standards, guidelines and presents manufacturer recommendations, which can be helpful to various stakeholders in specifying design requirement while considering lithium ion battery in offshore.
Waste Heat Recovery in Gas Processing by Organic Rankine Cycle
Authors: Al Ketbi Waneya , Sajjad Saqib , Al Jenaibi Eisa 
Published: November 2020

Abstract
ADNOC Gas Processing is looking into the energy saving opportunities to improve plants energy performance, aiming continual improvement and also for sustaining the already achieved efficiency improvement in varying operating scenarios. It is in line with the ADNOC Sustainability Strategy target for the Year 2030 which requires reducing the Green House Gases (GHG) intensity by 25% in Year 2030 considering Year 2018 as the baseline. Therefore, multiple avenues and opportunities were looked into to contribute towards this ambitious target. One of the promising contributors, having substantial potential of energy savings, is the Waste Heat Recovery. In this context, ADNOC Gas Processing has evaluated the option of utilizing waste heat from different heat sources across different plants using the Organic Rankine Cycle to generate power. Waste heat sources like exhaust gases from power generators, mechanical drive gas turbines, heaters and incinerators stacks, and low pressure steam condensers have been assessed. This opportunity of waste heat recovery exhibits substantial potential to contribute towards GHG emissions intensity reduction, reduce power import, improve energy efficiency and reduce the operating costs. The paper presents the techno-economic appraisal of the opportunity for the selected waste heat sources.
Vortex Induced Vibration for the Long Span Attachment Pipes on Jackets - An Optimized Solution
Authors: Samant Sachin , Pai Arun , Karuppusamy Kandasamy , Kamal Faris , Takieddine Oussama 
Published: November 2020

Abstract
Brownfield projects whether topside modifications or underwater modifications are always challenging in Offshore Industry. New facility attachments to the existing jackets in the form of J tubes, Utility Pipes, Risers etc. require clamped connections. It involves underwater removal of marine growth and installing the new clamps on existing jacket members. The allowable span lengths of these attachments pose a challenge to Engineer. Sometimes jacket members are not available to install clamps at the required location. This leads an Engineer to take misaligned and eccentric supports to satisfy the span length requirement. In few occasions this leads to the installation of the new supporting jacket member with clamped connections.
This paper presents an enhanced design concept for working out the maximum possible span lengths of these pipes considering associated vortex induced vibrations (VIV). These members are checked for VIV and VIV induced fatigue to determine spacing of the supports on jacket as one of the design criteria. This paper discusses the standard methods of the VIV check and gives a more enhanced methodology by which the spans can be increased without causing VIV excitations.
API Recommend Practice 1173 Third-Party Assessment Program: Pipeline Safety Management Systems in a Global Context
Authors: Burr Alexa S. , Toth S. David , Frazier Colin M. 
Published: November 2020

Abstract
In 2015, the North American pipeline industry completed the development of a framework for a Pipeline Safety Management System (Pipeline SMS) designed specifically for pipeline operators. American Petroleum Institute (API) Recommended Practice (RP) 1173 is the product of a collaboration between pipeline operators, state and federal regulators, and other engaged stakeholders (e.g. gas distribution, transmission, utilities, etc.) working towards the goal of zero incidents. The API Pipeline SMS Third-Party Assessment Program is designed to identify ways of empowering stakeholders to do their operation(s) and maintenance activities in a safe way, and identifying practical steps to protect communities, employees, and the environment from the pipeline safety risks. Incidents occur not because of a lack of knowledge, but failure to use the knowledge the industry already has. Many operators think that undertaking Pipeline SMS assessments is a difficult and complicated process, and as a result, it is often misunderstood. The API Pipeline SMS Third-Party Assessment Program is a proven and consistent assessment program that enables operators to break through PSMS barriers and implementation challenges.
New Generation of HTHP Water Based Drilling Fluid Changing Conventional Drilling Fluids Solutions
Authors: Hasan Hamdan Tariq , Traboulay Vaughn Reza , Husien Mohamad , Alblooshi Salem , Awadh Alhammami Mohamed , Qassem Hussain Mohamed , El Shahat Ayman , Osama Abd El-Meguid Mohamed , Arena Carmelo , Aung Tint Htoo , Panamarathupalayam Balakrishnan , Manzoleloua Cedric , Dmello Allwyn , Eyaa Clotaire 
Published: November 2020

Abstract
The conventional drilling fluid to drill the high-temperature wells are non-aqueous fluid. ADNOC used high-temperature water-based drilling fluid instead of nonaqueous fluid to drill the well successfully. High-temperature water-based drilling-fluid systems hold several advantages over non-aqueous systems from financial and environmental viewpoints. However, most conventional water-based systems start to become unstable at temperatures above 300 degF. This paper details the design and implementation of specially designed water-based drilling fluids based on custom-made branched synthetic polymer that meet these temperature stability requirements. The branched synthetic polymer exhibits superior rheological properties and fluid loss control, as well as longterm stability above 400 degF. Under static conditions, the high-temperature fluid shows no gelation, resulting in lower swab surge pressures while the stability of the highly branched synthetic polymer and enhanced rheological profile minimize sag.
ADNOC required a cost-effective drilling-fluid system that remains stable under static temperatures expected to exceed 375 degF. The longterm stability of the system was critical for successful wireline logging operations. In addition, the system was required to provide shale inhibition, hydrogen sulfide (H2S) suppression and enough density to maintain well integrity while drilling through anticipated high-pressure zones. The challenging intermediate and reservoir sections were drilled and evaluated using high temperature water-based system. This paper will discuss the successful execution of high temperature water-based system in one of high-temperature well in ADNOC field.
The Hybrid Strategy of Business Continuity Management for Offshore Facilities – A Case Study
Authors: Bunjongmanomai Somsak , Homanee Setawat , Chantabutr Sirodom , Ratanatanyong Suwitcha 
Published: November 2020

Abstract
Business Continuity Management (BCM) identifies an organization's priorities and prepares solutions to address disruptive threats. It supports the design and implementation of detailed plans to protect the value creating operations of an organization. However, Business Continuity Plan (BCP) for offshore oil and gas facilities is not commonly developed by all Exploration and Production (E&P) companies, thus exposing some smaller (E&P) companies to significant risks arising from business disruptions.
The proposed methodology was developed in accordance with the following standards; NCEMA 7001 (2015) Guidelines adopted by UAE government entities, ISO 22301 (2012) Business Continuity Management Systems and Business Continuity Institute (BCI) Good Practice Guide (2018). This case study demonstrates the application of these standards for a marginal crude oil E&P company encompassing offshore facilities.
The paper describes the business continuity plans developed for offshore facilities, which includeWellhead Processing Platforms (WPP), subsea pipelines and the floating assets, such as the Floating Production, Storage and Offloading (FPSO) vessel, or a Floating Storage and Offloading (FSO) vessel, based on various major operational disruptive scenarios e.g. the scenarios encompassing the loss of facilities, people and/or supplies etc.
Unlike the BCP for an office location, it is shown that a hybrid strategy (standby and post requisition) is more appropriate for offshore facilities due to the inherent logistical complications of an offshore operation. A standby technique is used for short-term interruption of the facilities, while a post-incident acquisition technique is applied for longer term unavailability incidents. An appropriate recovery strategies is developed for all case studies to achieve the Minimum Business Continuity Objective (MBCO) prior to the operation's full recovery. Finally, this approach facilitates the validation of the BCP.
Business continuity management is emerging as an essential part of sound corporate governance, but knowledge and experience in BCM by E&P companies is not yet widespread. The case studies presented in this research provides valuable guidance on the development of business continuity plans in accordance with international standards, and demonstrates how the implementation of BCM alongside an effective Emergency Response Program (ERP) increases the level of business resilience of an organization.
Extreme Extended Reach Drilling Depths with Ultra High Torque Drill Pipe
Authors: Awad Ahmed , Musleh Osama , Bordet Laurent , Baryshev Dmitry , Prim Matthew Thomas 
Published: November 2020

Abstract
A world-leading extended reach drilling (ERD) project in the UAE has successfully made a breakthrough, drilling several of the longest wells in the world from artificial islands offshore Abu Dhabi. A key enabling technology for efficiently delivering such wells has been the use of a single size string of ultra-high torque drill pipe throughout the entire well construction process. The drill pipe incorporates specially designed threads and tubular geometry to overcome technical challenges and enable ERD depths beyond 40,000 feet (12,000 m).
The drill pipe design is fit for purpose, incorporating the latest in thread technology to enable ultra-high operational torques. The connection pushes the limits of thread design with make-up torques (MUT) in excess of 70,000 ft-lbs for a 6½-in. connection and 5½-in. tubular body. Design considerations allow for fishability in an 8½-in. hole while accounting for equivalent circulating density (ECD) and standpipe pressure restriction that might otherwise limit the achievable drilling depths.
The drill pipe design was successfully used to drill more than 1,000,000 ft (300 km) across seven rig lines since the tubular entered service in early 2018. As of February 2020, zero failures related to the drill pipe have occurred. The incredibly high operational torque is continuing to allow wells to reach out further and further, with multiple wells now among the top 10 longest worldwide.
The drill pipe being of a single size has tremendously reduced the amount of tubular handling that must occur as it is no longer necessary to lay down and pick up other tubular sizes on each well. Hydraulic design considerations have proven to be sufficient.
This paper details the comparative evaluation of two drill pipe designs that enabled the operator to drill wells that are among the longest in the world. Insight into the operational benefits obtained by shifting to the new tubular design are also detailed.
Remote Activated Sliding Sleeves Improve Efficiency and Introduce Operational Flexibility to Offshore Lower Completion Design
Authors: Edwards Andrew , Tuffy Declan , Sweeney Kieran , Glennie James , Babazade Farrukh , Robertson Bruce , Murdoch Euan 
Published: November 2020

Abstract
This paper will portray the development and deployment of remote-activated sliding sleeve devices commissioned for use in a two-stage completion North Sea project. The sliding sleeves are required within the lower completion to provide access to the reservoir, protection to a control line and act as part of the fluid-loss envelope. Remote activation technology has been implemented to the sleeve designs to improve efficiency and introduce operational flexibility.
Three variants of sleeves were designed and deployed to facilitate well objectives. The first variant is run-in-hole (RIH) Open to provide a circulation path and subsequently closed post displacement activities. The second variant is RIH Closed and is distributed across the reservoir. These sleeves are remotely opened post Xmas tree installation and provide the tubing/annulus communication for production or injection. The third variant is again RIH Closed, but this is a purely mechanical sleeve to allow further access to compartments or different reservoir units later in the well's life. A variant of open-hole anchor with bypass capability was also developed and tested.
Remote-activated sliding sleeves were prototyped and qualified to API 19AC. In addition to the standard requirements of API 19AC, open/close cycles were also performed with lost circulation material-laden (LCM) fluid along with low hydrostatic pressure function testing. This latter testing is to allow for sequential functioning without having to shut in or choke back the well, instead functioning while the well is flowing or even under full operational drawdown. Three wells have been completed to date, two producers and one injector. The RIH Open sleeves have successfully acted as a replacement to a traditional fluid loss valve and the RIH Closed sleeves have allowed zonal isolation, selective water shut-off and reservoir management. The use of open-hole anchors has also been standardised, in producers to support future stimulation operations and in injectors to combat thermal contraction. Across all three wells the RIH Open sleeves have all been actuated successfully via Radio Frequency Identification (RFID) tag carrier or timer and the RIH Closed via pressure sequence and / or timer. The second producer also saw the first implementation of the staged clean-up functionality with sleeves opening at four different intervals over a period of 17 days.
Using Agile Saturation Distribution to Turn the Models into Democratic Knowledge for Faster Clastic Subsurface Characterization
Authors: Sugiharto Yudiyoko Ega , Ralphie Benard , Johare Dzulfadly 
Published: November 2020

Abstract
Although papers comparing some standard functions with saturation models have been published, no consistent review exists comparing the performance of most of the universal saturation-height function quantitatively. The universal SHF is fast and straightforward, but robust enough to account for limited data and while another full data acquisition and advanced analysis are in progress (partially obtained). The method can help the subsurface team in understanding the water saturation nature in quick turnaround time before the completion of ongoing volumetrics estimation. Two best practices of this workflow are rapid and robust.
The paper reviews three of the universal saturation-height methods, namely those proposed by Choo, Kyi-Ramli, and K-Function. The comparisons between modelled and measured capillary pressure measurements over the most common functions and through different reservoirs are discussed. The advantages and drawbacks of each method are highlighted. Each technique is compared by investigating how accurately they model the saturation-height profiles of several wells from Offshore Malaysia. The work was carried out to independently assess which equations should be tested first during saturation-height studies. The differences for each capillary pressure between the water saturations estimated using the equations and those measured on the samples are examined in both graphic and quantitative terms.
The results of this study show that Choo (2010) model is one of the better performing saturation-height functions. However, the best results are achieved using this function, but this method is also the most challenging to execute in petrophysical and static modelling software. Of the conventional equation-based approaches, the K-Function model appears to have the most utility and are recommended as first choice saturation-height models to test. It only has two inputs for the modelling comprising of RQI and HAFWL.
This study continues the extended concepts of Adams (2016) and Harrison (2001) to describe quantitative comparisons between modelled and measured capillary pressure measurements over the functions and through different reservoirs.
The review presented could not include all possible equations, but shows which of the most frequently cited functions, is likely to be of utility. Areas for future improvement are also highlighted.