bluuebunny/crossref_metadata_2025_split huggingface dataset:
Well Integrity Management in Brown Fields
Authors: Yugay Andrey , Vorozhikhin Sergey , Daghmouni Hamdi Bouali , Salem Al Shamsi Marwan Hamad , Yousef Alblooshi Abbas Ahmed , Silchenok Mikhail , Bin Ali Azlan , Al Mohammed Edries Ibrahim , Rinaldo Ferdian 
Published: November 2020

Abstract
Well integrity is a combination of several disciplines integrated into the different phases of the well lifecycle with ultimate objective to prevent well control incidents. The subject of this paper is about effectiveness of various well integrity monitoring techniques at different stages of the field life. It is based on actual Company lessons learned and recent experience in managing well integrity incidents, when all barriers got lost. Wellhead pressure monitoring is one of the most popular methods of well integrity surveillance. It is based on the double barrier envelope concept: primary barrier envelope is the one exposed to pressure; secondary barrier envelope is the one that will be exposed to pressure if primary barrier fails. Therefore, once the primary barrier fails, it is expected to observe pressure at surface as an indication of the failure. Therefore each well operator has internal fit for purpose wellhead pressure monitoring system. Some specific well categories might be monitored more frequently than another due to higher risks associated with these wells. Double barrier policy is a well integrity requirement well-known world-wide. This policy applies to wells with positive pressure at surface capable to flow naturally. This policy is the basement for wellhead pressure monitoring system. However, based on the latest Company’s well integrity experience, this system is applicable for green fields only, with brand new barriers installed and tested. In case of mature brown fields after several decades of production this system may not always work perfectly. It may happen that failure of the primary barrier envelope occurs in the wells with already failed secondary barrier envelope. In this case there is no any "grace" period to respond to the failure and we immediately get a well control incident reflecting in uncontrolled release of well media through failed barriers. Therefore at some point of field development the time comes when secondary barrier envelope is not reliable anymore and additional surveillance activity has to be implemented to ensure safe operating conditions in the fields. This paper warns well operators on the potential gaps in the well integrity monitoring that may lead to the severe incidents. Those gaps may not exist at the early stages of development but appears during the "transition from green to brown" field. The paper helps to recognize the period for activating additional surveillance techniques avoiding unnecessary OPEX impact. It also describes various surveillance techniques for secondary barrier envelope including leak detection, corrosion logging and pressure testing.
Multiport Selector Valve MSV – New Innovative Automatic Port Leak Detection System Delivers Accurate Well Testing
Authors: Toro Mario , Helal Rami , Shatalov Sergey , Markarov Nick 
Published: November 2020

Abstract
A key production measurement is the periodic well testing for both fiscal and reservoir management requirements and a key element is the use of a multiport selector valve (MSV) upstream of a multiphase flow metering (MPFM) system.
Typically, an MSV can connect to 7-wells (total of 8 ports, one spare) where the valve isolates the flow from one of the wells and connect it to the MPFM system. The production flow of the other wells is mixed inside the valve body cavity and is directed to a common header. This process is repeated for each well to measure all wells periodically and the key requirement for the valve is absolutely no leak from all wells flow into the well port connected to the MPFM. However, leakages through the valve ports seals occur, even to new equipment, and as a result, the well measurements are inaccurate.
An Innovative automatic port leak detection had been developed to eliminate the disadvantages of conventional multiport selector valves. Thus, preventing seal leakage, avoid valve operation when there is a leakage, inform personnel in case of a leak and replace seals in time and avoid any damage to valve internals.
The automatic leak detection is based on exploiting the use of a multi-function seat process and pressure switches measurements. In the case some particles (physical impurities or debris) are trapped between the port seals, the automatic leak detection system will automatically perform a cleansing procedure by retracting and pushing the valve piston back to the seat port, allowing well fluid inside the valve to flush away any kind of solids. If the problem remains a leakage alarm signal can be sent to the operator desk from the valve control panel thus ensuring total integrity of the connection between the well and the metering line connected to the MPFM for accurate well test measurements.
An accurate well test measurement using MPFM systems for multi-wells can be achieved only if there are no leakages from wells into the wells port seal being measured and this will guarantee confident measurements as wells operational benefits such as detecting valve malfunction, a substantial reduction of maintenance and major repair costs and ultimately extending the multiport port valve operational life.
Adnoc LNG Gas Turbine Integrity Assurance Achievement and High Reliability Implementations
Authors: Ranieri Antonello , Karam Suood 
Published: November 2020

Abstract
ADNOC LNG natural gas export facilities (five Gas turbines driving centrifugal compressors) had experienced blade parts liberation at the first row of blades because of Chlorine and Sulphur presence in air intake system. The objective is to identify all integrity risks and to implement advanced technical enhancements to restore critical gas turbines integrity.
ADNOC LNG team carried out Root Cause Analysis (RCA) study and investigation as per existing procedures. Team collected all the events and engaged turbine manufacturer to identify root cause through intensive analysis and studies. Also engaged metallurgical third part lab to identify the nature of encountered cracks and type of fractions. The investigation had the scope to identify the origination point of blade liberation studying the broken surfaces of the blades. From the metallurgical point of view, thorugh metal strucuture studies and magnifications of broken surfaces, it was seen a series of point where metal structure changed from its original composition, having a consequent drop in properties like strength. Furthermore, the broken surfaces was typical of a metal subjected to a constast stress. RCA concluded that gas turbine had suffered of Axial Compressor Blade Stress Corrosion. The major action plan to be implemented on fast track was to replace rotors with coated blades, then rest of RCA actions were applied. The implementations and enhancements are fulfilled jointly by ADNOC LNG and manufacturer successfully.
Main implementations are blade coating, upgrade of air filter elements and blades tip clearance optimization. The recommended enhancements were implemented and successfully arrested the risk of blades liberation to assure gas turbine integrity and sustainable gas export revenues. ADNOC LNG has successfully upgraded all axial compressors rotors and eliminated the risk of blades failure. Since applied enhancements, no further blades failure encountered confirming sustainable operations and integrity assurance. The same successful enhancements were also implemented at ADNOC LNG utilities gas turbines generator sets.
The aim of the abstract is to share and focus on success story of gas turbine integrity enhancements and improvements to assure gas export sustainability. Furthermore, it wants to draw reader attention to potential hidden issues that cannot be discovered during turbine operation in order to prevente major damages resulting in losing of turbine and production.
FPSO 4.0: Powering Deepwater Production and Optimizing the Lifecycle Performance of Offshore Rotating Equipment Packages
Authors: Sehgal Chirag , Khan M. Zeeshan 
Published: November 2020

Abstract
This paper focuses on solutions and strategies for conserving weight and space, reducing emissions, and leveraging data to optimize the performance of rotating equipment on floating, production, storage, and offloading (FPSO) vessels. It discusses design considerations for gas turbines in offshore applications (i.e., dry-low emissions technology, use of lightweight components, etc.) The paper also outlines a holistic digital lifecycle approach to FPSO topsides, which can help reduce capital and operating expenses, shorten project development cycles, and decrease offshore manpower requirements.
For illustrative purposes, the paper discusses specific power and compression solutions that were implemented on various offshore projects in 2017 - 2018, ranging from Offshore Brazil to the Bering Sea. It outlines how the equipment configurations helped operators meet horsepower requirements and emissions targets, as well as CAPEX and OPEX objectives. Additionally, the paper discusses how digital transformation can be leveraged to optimize FPSO lifecycle performance, delivering benefits such as 4-12 week reduction in project cycle times, ~$7 million reduction in CAPEX, and $60 - $100 million reduction in OPEX over a 10-year period.
Successful Project Delivery Through Effective and Well–Timed Operation and Maintenance Involvement During Project Life–cycle
Authors: Jaafar Zaharuddin , Zainuddin Muhammad Izuan 
Published: November 2020

Abstract
The continuous and rigorous endeavor in identifying key project successes or failures has been one of the most celebrated effort within the fraternity to advocate good project management implementation. Although the delivery method is unique from one project to another, perceivably there is no right or wrong formula that ensures outright success. It is often regarded that having an exceptional project manager leading a team that pays attention to collaboration between the project team and the contractors or manufacturers, guarantees a successful project delivery.
What is rarely looked upon is the contribution of the operations and maintenance personnel embedded as part of the team, which plays a vital role to the smooth and seamless transition from the task-oriented project, to the product-oriented operations and productions phase. Early involvement of this sort enables majority of the pain points anticipated during commissioning, start-up and finally during the handover period to be addressed much earlier during detailed engineering and construction phases.
The accomplishment of the recently completed Spheripol and Spherizone polypropylene units as part of the giga-project Refinery and Petrochemical Integrated Development (RAPID) which is located within the Pengerang Integrated Complex (PIC) in Malaysia, gives us the best insight on how project delivery can improve and flourish by putting the emphasis on small things that matter. Standing at USD 27 billion, PIC, the largest downstream investment by PETRONAS in Malaysia, consists of an integrated refinery and petrochemical complex, supported by several facilities which includes a raw water supply and treatment plant, an air separation unit, a cogeneration plant, a deep-water terminal and a regasification terminal. Like other plants complexes, it also has its own centralized utilities facility. Not many would think that setting the operational elements and getting the operations personnel involved as part of the team prematurely, will minimize technical gaps once the facility starts its operations. However, this unique approach has proven to be effective and successful for a major integrated project like RAPID.
The operational elements mentioned above include progressive participation and deployment of operations and maintenance personnel during front end and pre-award of execution contracts, assurance reviews (engineering, constructability and safety) and mechanical completion walkdowns. This gradual involvement evolves into a full leadership role during commissioning up until the process of starting up the plant. This study will show how the close collaboration between projects and operations teams, towards the successful delivery and integration of RAPID polypropylene plant can never come too early.
New Analytical Evaluation Approach to Select Sand Control Techniques in a Mature Field
Authors: Syed Abd Rahim Syarifah Puteh , Azman Mohd Fairuz , Awang @ Mohamed Zaidi , Ghonim Elsayed Ouda , Yang Juhari 
Published: November 2020

Abstract
Sand production is one of the most common issues in the oil and gas industry which impacted the production and equipment. Thus, downhole sand control is introduced to provide the mechanism for wells to produce with minimal sand production to surface and reduce the lifecycle OPEX of the well. Nevertheless, different sand control methods may influence the well production performance differently.
This paper demonstrates a comparative manner towards understanding of the effect of various sand control techniques on well productivity completed in a mature field. The methodology involves the use of statistical comparison of the actual production performance of three (3) main sand control methods installed over 20 years of production period in Field D. The approach includes in-depth assessment of the well production performance in relation to the recorded sand count and the intervention frequency ratio.
It is observed that the wells completed with OHSAS displayed remarkable production performance but high in sand production as compared to other sand control techniques. However, wells completed with CHSAS showed satisfactory production performance with good sand control. In fact, the CHSAS wells are still active and producing even after 8 years of completion without any integrity issue. For more advanced option i.e. CHGP, the wells showed comparable results with CHSAS both in term of performance and sand count. Depending on the proppant placing techniques, wells completed with HRWP have the best production performance, followed by Extension Pack then Circulating Pack. It indicates that more rigorous sand control design will effectively retain the sand downhole but reduce the well productivity as well. Therefore, the key is to find the balance between these two variables in determining the optimum sand control option especially when different sand control methods require different level of investment with certain expectation in return.
The evaluation approach described in this study offers an easy guide and benefit the practicing engineers to select the optimum sand control in addition to theoretical studies that based on geo-mechanics analyses, PSD, SRT etc.
A Game-Changing Technology for Cementing in Highly Deviated and Horizontal Wells Using Interactive Mud-Sealing Cement System
Authors: Orprasert Choosak , Prasongtham Pattarapong , Abu-Jafar Feras , McManus Ian , Thanasarnpisut Viraphon , Johri Ambuj , Duong Anh , Shafie Jumaat Mohd 
Published: November 2020

Abstract
Effective zonal isolation in wellbores with a challenging mud removal environment is well known to be very difficult to achieve. In wells at the technical limits of Non- Aqueous Fluid (NAF) removal prior to cement placement, cement bond quality and hydraulic isolation can be compromised by leaving channels behind the casing, which can result in several long-term well integrity issues. An Interactive Cementing System (ICS) is developed through special experimental methodologies to mitigate mud channeling issues and improve zonal isolation, by immediately interacting with any residual mud channels left in the well after cement is in place, hence reducing the permeability of mud channels and sealing off microannulus gaps.
Casing centralization is considered to have the greatest influence on mud removal efficiency because it directly affects the flow movement on each side of the wellbore. Mud removal has been studied from numerical simulations, laboratory experiments, and field results, and these show that good mud removal can be achieved only when adequate casing standoff is achieved during cementation. In modern wells where there are many operational restrictions and limitations, especially in highly deviated and horizontal wellbores, final cement designs may not allow good casing standoff and thus not all of the best practices for effective mud removal can be applied.
The objective of the innovative cement system is to have a design that interacts with residual mud in the annulus to "fix" the channels, thereby enhancing cement bond quality and zonal isolation. Two detailed case histories of the application of this technology in the development campaign showed visible improvement in cement bond logs using the ultrasonic imaging tool as compared to offset well that was cemented using a conventional cement system. After two successful implementations, the ICS was selected as the cement system of choice for wells with challenging mud removal.
A Systematic Approach for Evaluating Entire Production System Value Chain to Deliver the Dynamic Market Production Demand Using an End to End Production Simulation Process
Authors: Alsaeedi Ayesha Ahmed , AlHarethi Fahed Ahmed , Alzeyoudi Mohamed Ali , Al Bairaq Ahmed Mohamed , Reddicharla Nagaraju , Soni Sandeep , Tripathi Deepak , Hidalgo Melvin , Raj Apurv 
Published: November 2020

Abstract
Within a complex and dynamic production system with several operational challenges, maintaining a steady stream of throughput to meet the production targets based on the day to day well availability is a key business driver. This paper discusses an all-inclusive integrated modeling approach to evaluate the supply side of the production value chain, i.e. reservoir & well deliverability and the demand side, i.e. production targets.
The process starts with the representative inflow reservoir performance and well performance generation. In the second step, the key business requirements are applied as quantified parameters such as shareholder guidelines, minimum well production, and maximum drawdown. The most conservative figure was taken to ensure the long-term reservoir health. Subsequently, the target production was estimated from each reservoir based on the current strategic business plan. Lastly, an allocation mechanism was applied, honoring the required target-production and the well capacity to give a unique solution.
The major output of the entire process was achieved by estimating the well targets and probable shortfalls, honoring the process constraints within the production system. Also, the output of this target estimation was transferred to the surface network simulation to consider the back pressure impact and provide adequate outputs such as choke settings and wellhead pressure settings.
This outlines process provides a standardized approach that is utilized to cater the several business needs, such as minimizing the liquid loading, optimizing the drawdown to maintain a stable reservoir performance, and health.
Starting from producing layers to the delivery point, this process uses an integrated approach encompassing the various components in a complex production system such as reservoir capacities, fluid composition, well behavior and network capacities to assure a representative forecast. This approach is crucial in a gas-producing operating asset as the fluctuation in demand can be easily fulfilled using a seamlessly integrated approach that takes care of the dynamic operations variables such as well availability, surface facility back pressure, etc. in a single platform.
The approach improves the efficiency of target estimation significantly as the previous tiresome work of updating the simulation models and running the isolated calculation have been replaced with few clicks within the workflow.
This holistic approach is in line with the overall corporate strategy of integrated reservoir management (IRM) guidelines ensuring the long-term development plan and strategy is inherent to the overall process.
Intelligent Annual Reservoir Performance Reporting System i-ARPR – A Fascinating Journey from a Concept to Reality
Authors: Khan Muhammad Navaid , Al Beshr Manal , Mohan Richard , Al Marzouqi Mohamed , Al Khatheeri Abdullah , Al Nuaimi Mai , Abdou Medhat 
Published: November 2020

Abstract
The ever-increasing need for resilient strategies demands the supreme understanding of business uncertainties and the execution risks. For the National Oil Companies like, ADNOC, the annual reservoir performance review (ARPR) is a process of paramount importance, as it provides a holistic overview of the reservoir performance status for each ADNOC field on yearly basis. It unfolds the subsurface performance issues, uncertainties and risks, and steers the decisions of Business Plan sanctions.
The ARPR execution demands a tremendous amount of time and effort to assimilate information and create a consolidated decision support package. In the absence of an automated process, the creation of insightful analytics, proper tracking of actions and maturation of value-driven opportunities become unmanageable. Thus, the automation of the process asserted to demonstrate a significant reduction of the data preparation time, increased multidisciplinary collaboration, centralized data archiving and integrated dashboard generation.
A multidisciplinary team of ADNOC's subject matter experts joined forces to develop a fit-for-purpose automated solution (i-ARPR) that underpins a sophisticated subsurface knowledge bank that leverages advanced analytics and digital technologies to integrate key reservoir performance parameters automatically and provides insights to support crucial business decisions. It allows users to collaborate via an automated guided web-based workflow to build the analyzed content for the ARPR report for a given Field, using data previously loaded and approved. The content is built bottoms-up from a defined list of Elements (Plots, Tables, Images and Text) along with analysis and insights contributed by Subject Matter Experts (SME's), into sections of the report that are collated and further expanded with insights and conclusions by designated Sections Editors.
The solution enables assigning tasks to users at various supervisory and coordinating levels through an automated governance system. It provides means to monitor the progress of the work, approve the content of Elements and Sections, and review the concatenated ARPR document for final approval. All the integrated analyses get stored into the corporate repositories for any future utilization in data mining and advance analytics workflows.
The automated solution (i-ARPR) has enabled efficient data gathering, and its visualization has fostered multidisciplinary collaboration and has provided 66% more time to the engineers to analyze the information for identifying risks and opportunities. Over $50 Million OPEX saving is estimated during the first three years of the project implementation in 17 upstream assets within the ADNOC Group.