bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Innovative IR 4.0 Solution Against Leaks Utilizing a Fully Integrated Pipelines Management System
Authors: Wathnani Abdulkarim , Hussain Badr 
Published: December 2021

Abstract
This paper demonstrates the Saudi Aramco Khurais Facility (KhPD) successful commissioning of the A Fully Integrated Pipelines Management System, in an effort to enhance its environmental emission performance. The project team conducted an assessment conceptually right from the beginning, to ensure that the value creations from this initiative can be realized, and the project remain cost effective and safely executed while meeting environmental objectives. Following successful deployment, the Khurais team carried out post installation performance assessment to ensure the outcomes and objectives from this project has been impacted positively. This paper covers the fully implemented solution to manage pipelines assets and enchantments followed by Saudi Aramco Khurais producing facility (KhCPF) Objectives: Share how a corrosion challenge of multi-phase flow within pipelines led to installation of a comprehensive solution to Pipeline Management Systems (common header connects all compressors) and how it was resolved through integration between two different systems. In addition, highlight how this approach enhanced the pipelines reliability, safety and most important the big environmental impact that helped Saudi Aramco to reduce its carbon footprint.
Understanding the Impact of Monsoon Season in Malaysia Water Based on Data Analytics for Planning and Executing Drilling Operation
Authors: A. Halim Rahimah , M. Yusof M. Hatta , M. Khalid M. Hanafi , Wong Hao Xiang , Abu Bakar M. Aizat , Sulaiman M. Zarkashi 
Published: December 2021

Abstract
Drilling operation in Malaysia are typically from offshore, thus offshore weather condition does contributed to the success or delay of a drilling operation. Wait on Weather (WOW) especially during monsoon season in Malaysia has impacted Operator's drilling operation, thus incurring additional cost to Operator. Monsoon season in Malaysia is typically from November to February every year. This paper will discuss and share the statistics of actual WOW happening from 2008 to 2019 in Malaysia water especially for jack-up rig (JUR) and tender assisted drilling rig (TADR) which are two common rigs in Malaysia water. The data was collected from one of the drilling operator in Malaysia. These data will be of assistance to Operator in better planning and executing drilling operation with the actual statistics as the risk factor. WOW is considered as non-productive time (NPT), thus NPT data gathering from Operators in Malaysia water were conducted. Data was then filtered to achieve the WOW data. WOW data was segregated between region in Malaysia which are Peninsular Malaysia (PM), Sabah (SB) and Sarawak (SK) as well as rig type, which are JUR and TADR. Distribution analysis were made to calculate the average and observe the maximum numbers of actual WOW occurrence. Further analysis was made to zoom into monsoon season in Malaysia which typically in November to February. 11 years data is generally good coverage for the analysis since it covers the up and down of oil and gas industry. Analysis was also done for both mob/demob and operation stage where it can be observed that WOW for mob/demob stage during monsoon season is significantly higher compared to operation stage. At the end of the analysis, the average or maximum numbers of WOW will be shared, and it will be used as recommendation for future projects to consider these figures as WOW risk factor and embed in the planning stage. This paper will help not only Operators in Malaysia water but the host authority on understanding the WOW risk factor during monsoon season. As WOW is not something that can be predicted, utilizing the standard results from actual statistic data for the past 11 years will assist engineers to incorporate the WOW risk factor during planning and execution stage. Rig and project sequencing can be optimized with understanding of WOW impact thus reducing the value leakage during operation due to WOW.
In-Line Inspection of Offshore Non-Piggable and Challenging 30" Subsea Flare Line
Authors: Al-Messabi Saqer Saleh , Zebidi Anouar Abdul Qader , Al Hosani Khaled Abdullah 
Published: December 2021

Abstract
The objective of the paper is to present the success story of carrying out an in-line inspection (ILI) on a 50 years old offshore subsea flare line. The project was particularly challenging because the 30" flare line had no pigging facilities, a reducer, a subsea tie-in connection, as well as other restrictions. The paper shall outline the approach and methodology adopted to conduct the inspection in a safe and successful manner while adhering to the company and government health, safety, and environmental regulations and meeting the shutdown window.
The 1 km long 30" flare line runs from a collector-separator platform to a flare tower. A site survey was conducted to identify process, space, and rigging related requirements. The shutdown window was allotted and fixed by the production teams. The line was first flushed to remove the hydrocarbons using a pumping spread mounted on a support vessel. This was followed by various modification works in addition to rigging up the temporary pigging traps. The works enlisted the help of support vessels and scaffolding teams. Extra controls were implemented due to the low maximum allowable operating pressure and the dirty pigging water in order to safeguard the property and environment. Eventually, 22 cleaning pigs were launched a in a train fashion. An Ultrasonic (UT) ILI tool was then used to gather information on the pipeline. Finally, the pipeline was dried using foam pigs.
The operation was a success mainly because of the planning factor. Many activities were integrated including the availability of a maintenance barge which played a huge role in the operation. This was the first pigging operation on the flare line which was commissioned in 1971 - a total of 185 kg of debris was collected. Moreover, the UT inspection provided quantitative data which enabled an accurate assessment of the subsea pipeline integrity status. It is estimated that USD 4 million were saved by completing the works mainly through efficient planning and utilization of in-house available resources. The inspection results will form a cornerstone in development of future asset replacement plans for this category of flare lines. The success has created potential savings for another 21 challenging flare lines planned to be inspected for the next 5 years.
The approach highlights the steps taken to conduct the quantitative ILI of an aged flare line (50 years old), with various inherent challenges, to explore the possibility of accurately inspecting and extending the remnant life of aged assets that are un-piggable, in a safe and environmentally friendly manner. Thus, resulting in positive impacts in savings and further optimizations in the asset replacement plans
Sustainable Production Enhancement of Valuable Products Via Operational Rectification
Authors: Agung Margono , Heryadi Wawan , Selladurai SanthoshKumar , Ventkataraman Ramesh , Al Qubati Ahmed , Yuniarto Dwiyono , Al Shamsi Abdullah 
Published: December 2021

Abstract
ADNOC LNG lies in the middle stream of the value chain, receiving and processing LP and HP gases from ADNOC Offshore. Supporting ADNOC Upstream's current oil production and future growth strategy while reducing its associated emissions of the process by delivering the associated gases to ADNOC LNG battery limit
ADNOC LNG processes associated and non-associated gases to produce LNG (Liquefied Natural Gas), Propane, Butane, Paraffinic Naphtha (P. Naphtha) and Sulfur. LNG constitutes Methane, Ethane and a little Propane and butane, with minimum constraints on GHV and density. In order to deal with market competitiveness in the context of a potentially prolonged low-price environment, ADNOC LNG has embarked on various initiatives to maximize its production by driving agility and efficiency throughout the value chain process. Delivering upon efficiency improvements, one of the contributing studies included optimizing the propane content i.e. reducing the C3 content, in LNG
Propane content in LNG has been varied, within operational limits, to maximize production of propane, which is more valuable/profitable when compared to LNG, whilst maintaining minimum LNG specification. In addition, slighting higher feed gas has been processed, to maintain LNG production rate. This has been achieved without hampering the plant stability.
The extensive review and analysis of the rectification units has been conducted as well as optimization in terms of temperature profiles and reflux flow rates was able to generate overall better product purification, thereby increasing production of desired and more valuable products.
This study has driven the investigation of additional benefits in production enhancement and quality improvements as the market value of Propane is relatively higher than that of LNG and thus yielding greater benefits. The overall performance trial basis deduced a total added benefit equivalent to 9 MMUSD/year YTD for train 3.
My Personal HSE Commitment Program – A Valuable Web Portal to Improve the HSE Leadership at a Workplace
Authors: Mohamed Mohamed Mokhtar 
Published: December 2021

Abstract
Safety at work is not just a priority, but a fundamental value, shared by employees, contractors and local stakeholders.
People are both as the starting point and the final goal of all its actions. This is why we work hard to ensure the safety of each of us and those around us, in order to eliminate all accidents. we are all committed to spreading and strengthening a culture of safety among all our people, employees or contractors, as an essential part of our work. Companies develop campaigns and projects to promote a safe and healthy behavior in any workplace and, more in general, in everyday life.
Virtuous tools and means of communication include workshops, theatre events and round table discussions, as well as video clips sharing what we learned from past safety hazards and the HSE Safety Golden Rules, our key safety rules. The continuous involvement of top management, contractors, representatives from local communities, or external guests, increases its commitment to safety.
This paper presenting one of the effective program which is designed and launched by an Oil & Gas Company so to allow all HSE leaders to self-evaluate their level of commitment towards HSE-related aspects and plan a number of important activities that would ultimately increase one's level of HSE commitment and enhance the safety culture through a Web Portal program called " My Personal HSE Commitment".
The portal provides the possibility to develop an action plan related to specific corrective and/or proactive actions/tasks that the user wishes to keep track of.
The most important part is also, The Web tool is furthermore capable of generating a personal HSE Commitment Poster that the user "The Safety Leader" can share worldwide thanks to the portal integration with Microsoft Outlook. Moreover, users can search others Posters – allowing for the widest dissemination of one's HSE Commitment among other users.
By applying this program, companies engaged all its Leaders and Management in the process of creating a strong HSE Culture and also, increasing the competition between leaders and program users by allowing each one to get access to others’ commitment posters.
By taking part of this program, each user can see - online - his direct HSE Commitment and be aware of others’ results which is creating a strong and transparent ability of positive competition and real outcomes based on each one's performed activities.
Once the companies applied this program, we can immediately see a considerable increase of HSE activities performed by all users and HSE leaders worldwide and this paper highlighted the results achieved & HSE performance improvement thanks to the way this program was created which helped a deep involvement of each leaders in the process of raising the HSE commitment of the company's management.
An Integrated and Digitalized Approach to Reduce the Well Failure Index During Covid-19 Global Pandemic in Shushufindi Field
Authors: Maulidani Oki , Escalona Pedro , Paredes Monica , Sierra Maria , Bonilla Christian , Villalobos Jorge , Bravo Luciano , Estevez Diego , Pineda Alexander , Chicango Edgar , Ramos Geovanny , Rodríguez Randall , Alabuela Luis , Freire Carola , Guaman Juan 
Published: December 2021

Abstract
The Covid-19 pandemic is an unprecedented condition to the global economy including the oil & gas industry. The ability to adapt to the imposed changes, requires creativity, innovation, digitalization of processes, and resilience. This work will show a novel integrated approach around four pillars which had improved operation efficiency and brought monetary value during a challenging 2020 in Shushufindi field, Ecuador.
The first pillar is new technology adoption. This aims to extend run life of critical equipment resulting in a higher well productive time. Examples of adopted technology: Chrome-enrich tubulars, downhole microcaps chemical deployment, de-sander and multiphase/extended gas handler. The second pillar is the P3 process (Pre-Pulling-Post) to quickly and effectively find the root cause of well failure that leads to definite remedial action. Digital enabler is the third pillar, its value come from reducing operational downtime and risk by using real-time surveillance capability, remote control, and data intelligence. The final pillar is to re-establish an effective communication with all stakeholders.
Various dashboards have been developed in order to provide the big picture of actual field condition in quickly manner as well as implementation of ESP real time surveillance & diagnostics, real time multiphase production test, and chemical treatment automation. Workshops, online technical, and service quality meetings are regularly conducted to ensure that recommendations and opportunities can be executed properly including contractual negotiations to enable new technology implementation.
Despite all the restrictions during covid-19 pandemic and some force majeures in 2020, this integrated and digitalized approach has resulted an outstanding outcome: Well failure index reduced from 0.62 in 2019 to 0.41 in 2020; Production deferment related to well failure declined significantly from 2,420 bopd in 2019 to 1,259 bopd in 2020, which translate in savings of $16.8 million dollars. In addition to that, there was a reduction on operational cost from $26.3 million dollars in 2019 to $15.2 million dollars in 2020.
This proven initiative has been supported and recognized by all stakeholders. Some new technologies and digitalization projects are in the process to be implemented in Shushufindi field as part of Ecuador digital strategy 2022. This successful integrated and digitalized approach can be adopted in other fields and will generate a huge business impact.
High Definition Acoustic and Temperature Logging for the Diagnosis of Complex Annuli Leaks and Communication
Authors: Obaid Hashem , Ashby Scott , El Sheshtawy Mohamed , Ikhsanov Niyaz 
Published: December 2021

AbstractMaintaining annuli integrity is critical for safe and optimized well operations. Monitoring of tubing casing annulus (TCA) and casing-casing annulus (CCA) pressures is mandatory as it gives a direct indication of possible seal or tubular failures that may lead to a negative impact on HSE or well production. In cases where the observed annuli pressures suggest leaks and possible communication between tubing and TCA or TCA and CCA, a comprehensive plan should be put in place to detect and evaluate the possible leak sources and paths that will allow for proper remedial actions.Logging techniques using spectral noise logging (SNL), and high precision temperature Logging (HPT) are one way to diagnose the source of a leak and communication path between 2 adjacent casings (for example TCA and CCA). The operation is performed by running the HPT and SNL log under shut in conditions to establish a base line, followed by logging under dynamic conditions. Dynamic conditions can include bleeding off the TCA pressure while all other annuli and tree valves are shut-in and injecting into the tubing-casing annulus while bleeding off the CCA.The dynamic passes aim to activate the leak points. The SNL and HPT will capture the corresponding temperature and Spectral noise events revealed by the fluid flow though the leak points. These are compared to the base line shut in logs. The SNL is run in stations and can capture noise generated by fluid movement in a wide range of strength (decibels) and frequency within a wide scanning radius, while HPT can capture minor temperature changes of 0.02 Deg F.The paper will discuss an example where the HPT and SNL were run along with a set of conventional sensors such as GR, CCL, and pressure in a HPHT gas well to diagnose leak points and a possible communication path between the TCA and CCA. The Logging operation was carried out rig-less with minimum intervention using wire line under the shut in and dynamic conditions. Spectral noise logging precisely captured the leak points and drew a clear picture of the casing integrity breaches in multiple points.The results of the diagnostics and evaluation will now be used to design the appropriate remedial actions required to restore the well to the desired condition for production.
High Performance Tailored Mechanically Enhanced Cement Slurry Helped in Delivering Dependable Barriers Across HPHT Reservoir: Case Study from UAE Offshore
Authors: Manga Patrick , Mohamed Sherif , Bhaisora Devesh 
Published: December 2021

Abstract
The concept of zonal isolation has evolved recently addressing new industry challenges to provide dependable barriers throughout the life of the well. This helps ensure long term well integrity for safer and more efficient hydrocarbon production, especially for the fields predicted to have a long lifetime. This leads to tailoring of cement slurry designs for superior mechanical parameters to avoid deteriorating them under post cementing operational loads.
Following cementing best practices is a key parameter to achieve a successful cementing job, however adequate mechanical properties will help a cement slurry to withstand all the cyclic loads that the well will experience during its lifetime. Determining these properties and tailoring cement slurry designs to meet these properties will help ensure that the cement slurry will still survive these loads, all the way from placement until it has experienced all the post cementing operational loads including but not limited to multiple pressure testing, unloading the well, perforations, various thermal loads during well production, hydraulic fracturing etc.
The tailored cement slurry was able to provide an adequate solution of such challenges faced by an operator in Offshore UAE under a high pressure – high temperature (HPHT) environment. Stress modelling was performed for the life of the well considering post cementing operations. This helped in determining optimum mechanical properties required for the cement slurries considered. Specialized testing was performed in both lab and yard to achieve such properties for field execution. Based on various stress and hydraulic modelling, slurries ranging from 13 to 17.5 ppg were designed and pumped successfully in the wellbore.
Post cementing bond logs showed adequate placement of a tailored dependable barrier across a complete wellbore including an HPHT reservoir section. This approach can be used for wells with similar challenges around the world for long term zonal isolation.
Accelerating Digital Transformation in E&P Business
Authors: Karim Anak 
Published: December 2021

Abstract
What is Digital Transformation?
The intersection and confluence of four technologies – elastic cloud computing, big data, artificial intelligence (AI), and the internet of things (IoT) write (Siebel, 2019) is fundamentally changing how business and governments operate in the 21st century. It is somewhat of necessity as to how the industry and markets must behave today and some describe using digital technologies and advanced analytics for economic value, agility, and speed.
Industry analysts are in unison when they say that "investing in technology is not the same as digital transformation", it does not simply apply to changes in the company IT systems or simply the migration of company business processes, systems, and tools to funkier platforms with "cool" user interfaces. (Priyadarshy, February 2018) rightly said that while the E&P industry is more than 100 years old and has seen many ups and downs, the prolonged and cyclical impacts of decreased oil prices since 2014 warrants the need for transformational modification for the industry to remain operationally viable.
The Upstream sector did start the digital journey from many decades ago and with incremental improvements. Among the first steps being the creation of data via traditional supervisory controls and data acquisition systems (SCADA) and ingestion of operations report which were not fully digital such as daily operations, drilling and log reports. Over the years after that, as further back as two decades ago, the E&P industry claims to have adopted digitization and digitalization in the form of digital oilfields, however, this has failed to generate significant economic value (Priyadarshy, February 2018).
Cutting Re-injection CRI Uncertainty and Risk Assessment
Authors: Samy Ayman 
Published: December 2021

Abstract
It is the responsibility of oil and gas operators to recycle or dispose of drilling cuttings in a safe and environmentally friendly manner. Environmental regulations are very strict in establishing that green operations and cutting re-injection be as clean and friendly to environment as possible despite the associated challenges and cost. It is the preferred technique by the majority of international companies.
Cutting re-Injection operations include grinding down the drilling cutting to small particle sizes and mixing them with a water-based fluid (mud, water, gel) to form a slurry. The slurry is then pumped under high pressure into a disposal formation where fractures can be initiated and propagated. Existing wells can be used as appropriate by targeting watered-out formations far from hydrocarbon- bearing zones; sometimes operators drill new wells purely for cutting reinjection purposes.
The main sources of uncertainty include reservoir heterogeneity, permeability, pore throat size and fluid leakoff rates into the formation. The optimum scenario is to pump the cutting re-injection slurry into a very high permeability formation where screening out, plugging or well packing is unlikely, assuming solids are suspended and are completely lost into the formation. This scenario can only be feasible if the formation pore throat size is much larger than the solid size.
This paper presents how to conduct risk assessments for all possible scenarios considering all sources of uncertainties. The paper also shows that under some circumstances it is better to pump the cutting slurry into a very tight formation, such as shale (closed system), than a permeable formation with a high degree of uncertainty where screenout potential risk is most likely.