bluuebunny/crossref_metadata_2025_split huggingface dataset:
Driving Operations Excellence During Covid-19 Pandemic by Capitalizing on Digitalization
Authors: Arif Muhammad , Al Jneibi Abdulla Mohammed 
Published: October 2022

Abstract
The COVID-19 pandemic has caused significant disturbances to the ways businesses operate, and has driven the entire industry to re-evaluate its operations. Although the full impact of the disruption will not be understood for some time, however, many companies are now beginning to re-examine and use lessons learned to become more resilient moving forward.
The Fourth Industrial Revolution (4.0) in Oil & Gas Industry creates a dynamic landscape where Operational Excellence (OE) strives for stability, quality, and efficiency while continuing to serve an increasingly demanding customer. Operational excellence is a journey, not a sole destination. Operational Excellence is a key strategic enabler to mitigate the impact of COVID-19 on shape the business of tomorrow.
In line with the company vision of digitalization, a number of initiatives were considered for studies and further evaluations to facilitate remote operations through digitization. Below is list of initiatives those were successfully implemented to promote remote field operations.
Critical equipment like compressors and pumps startup sequences development. Establish communication of wells subsurface (downhole) sensors with the control room for real time data monitoring. Development of wells start up sequences to facilities wells startup from control room. Real time monitoring of wells annulus pressure from control room compared to traditional field monitoring. Reset of Emergency Shutdown Valves (ESD) from control room instead of field.
All of the above proposals have already been implemented. In-house field operations implementation resulted in huge Capital as well as Operating Expenditure saving. By enhancing remote operations, essential benefits are achieved including capability to faster and more effective decision-making and improved HSE measures.
Enhance production and reservoir optimization by real time data monitoring and troubleshooting. Enhanced well integrity by real time annulus pressure monitoring. Enhanced HSE by eliminating Confined Space Entries (CSEs) and exposure to toxic H2S. Reduction and operating expenditure (OPEX) Reduced dependency on human leading to less human error. Reduction in capital expenditure (CAPEX) Enhanced life of critical equipment
Operational Excellence played its role with a value improvement objective. Rather than replacing successful practices and programs, Operational Excellence knitted them into a larger, fully integrated tapestry woven to increase value produced within the overall business strategy which is very evident in this scenario.
This case study is blend of Digitalization, Operations Excellence and innovation representing Management support to employee to solve current issues during COVID-19 pandemic. Such support is always beneficial for the company and employees.
Repairing Seawater Intake Basin With 100 MM$ Saving by Avoiding Production Cut and Optimizing Capex
Authors: Venkatachalam Saravanan , Ray Tapas , Shayea Mohamed Abdulla 
Published: October 2022

Abstract
There was an immediate requirement for a low-cost fast-track solution to tackle the integrity threats of a Sea Water Intake Pumping Basin at an Offshore Island location. The intake basin, which is more than 40 years old and has gone through minor skin repairs 25 years back, houses all the fire water and cooling water pumps to meet the demand of 1 million barrel per day Oil Processing Plant with 7 nos 1-Million Barrel Crude Oil Storage Tanks.
Sea Water Intake Basin is a box-type concrete structure divided into 7 Bays (compartments) separated by concrete walls or slabs wherein fire water and cooling water pumps are mounted. However, integrity condition of the basin was very alarming with half of the 300mm concrete thickness lost in most of the places of pump mounting slabs. As the intake basin is linked to two main systems of supplying cooling and fire water, failure of the intake structure would render the plant un-operational and lead to adverse impacts including plant shutdown.
The conventional way of repairing the basin would call for the outage of 2 of 3 cooling water pumps for 4 days causing around 500000 barrels of daily oil production cut. As 2 fire water pumps are required to be available always, the repair work would also cause outage of 2 of 3 fire water pumps for 4 days, necessitating a temporary fire water arrangement at a cost of around US$10 million. The challenge was how to repair the intake basin by minimizing and/or avoiding production cut and, at the same time, ensuring uninterrupted supply of fire water during repair, and reducing project execution cost from US$17 million to the extent possible.
A scheme was developed to avoid shutdown of critical pumps through use of buoyancy-assisted Temporary Support Structure and quick-setting concrete in dynamic condition as well as by optimizing plant parameters to reduce the cooling water demand. The scheme, executed at a cost of US$ 4.6 million, resulted in an overall savings of US$100 million.
This paper presents the optimized scheme and execution methodology for the basin repair duly avoiding total shutdown of essential fire and cooling water pumps. Also, this paper highlights how in-house Technical Support can contribute towards "More Profitable Upstream" by providing a fit-for-purpose and cost-effective solution to Company's business needs.
Well Integrity Surveillance with High Sensitivity Temperature Distributed Sensing
Authors: Chavarria J. Andres , Grubert Marcel , Minto Chris , Adams Euan 
Published: October 2022

Abstract
Increasingly well integrity monitoring is being done with fiber optic temperature and acoustic measurements. Historically temperature and acoustics have required two separate types of systems. Advances in fiber optic sensing have resulted in temperature measurements that can be conducted using an Interrogator Unit (IU) that is traditionally used for distributed acoustic sensing (DAS) acoustics analysis. The Rayleigh based Distributed Temperature (RDTS) measurements are sensitive to a 1/1000th of a degree and can be used to assess subtle integrity issues like leaks or problems in the various annuli of wells. It is this great sensitivity to small temperature fluctuations that is the focus of this paper. These DAS measurements have higher sensitivity than conventional DTS measurements and can illuminate previously unexplored wellbore dynamics.
Various measurements with fiber optic cables were conducted with DAS IU's in different engineering and downhole settings. The DAS measurements in wellbore conditions were processed for temperature focusing in the low frequency content of the signals. The measurements were initially validated against other sensing tools like DTS (Raman) and PT gauges to ensure that the temperature changes measured by the DAS unit are representative of real thermal regimes. Measurements were taken from a well setting that included permanent fiber optic cable cemented behind casing. However, these same tools are deployed in wells where the fiber is installed attached to the production tubing hence reducing deployment costs.
The DAS data processing was processed for temperature fluctuations by focusing on low frequency components where fluid regimes reside. Fluid movement within the wellbore was identified by small temperature changes recorded by the IU. These fluid dynamic processes were subtle and quiet enough that a traditional acoustic analysis was not able to identify anomalous zones. The resulting measurements were able to determine fluid velocities illuminated by temperature changes. We show how high sensitivity RDTS signals capture small temperature features and various fluid dynamic responses within the well not possible with other tools. The responses from the system clearly showcase quiet zones above which clear entry points of fluids can be identified as the origin of leaks.
Subsurface to Surface Congestion Management with Holistic Sustainable Development of Super Giant Multi Stacked Brown Field
Authors: Al Shehhi Mohamed Ali , Al Naqbi Hajer Khamis , Alhemeiri Sultan Sameer , Chellappan Sanjeev Kumar , Soares Sofia Machado , Idicula Anoop Pappy , Khan Sara Hasrat 
Published: October 2022

Abstract
Continual development of multi stacked super giant brown field in Abu Dhabi, over 60 years, has induced high congestion at surface resulting in challenging wellhead placement, rig movement and overall field connectivity. The conventional surface to subsurface approach has led to an increased number of undrillable wells, which impairs future developments and consequently, the ability to meet production targets and manage the field proactively.
This paper proposes an alternative to the surface-subsurface usual development solution that can unlock existing reservoirs potential, while being cost conscious and flexible to cope with business uncertainties and dynamics.
Working towards ensuring future sustainability of a brown field has proven its own complexity in developing additional value with minimal cost. Intensive focus is required on the critical factors that play a key role on brown field investment such as subsurface and surface congestion, HSE (Health, Safety, Environment), aging of facilities and it's replacement plan, and environmental issues. One such key factor is the subsurface and surface congestion, which is especially complicated due to different development schemes for each of the stacked reservoirs based on their API gravity and varying reservoir quality. The Shared Earth Model was established due to the absence of a holistic approach to strategically sustain the expansion in the brown field growth till the end of last oil/gas production drop. It is essential to allow all stakeholders to be exposed and visualize the subsurface data openly to collectively decide on the best way forward for each project investment, focusing in sector-by-sector growth. Another objective is locating surface facilities that are of lesser interest to subsurface development and plan their opportunistic removal (when conflicting with the subsurface interests), which will result in a dramatic decrease in undrillable wells by creating space at surface for the drilling location resulting in higher gain by giving priority to oil/gas reservoirs proposed development pattern. There are also challenges to proof quantitively the subsurface congestion and report the long-term risk collectively, which were addressed while developing this system. Allowing each system to talk to each other and work towards digitalization of the entire system for the full field development could not be achieved without this subsurface data platform.
Improvement of Artificial Lift Pumps Run Life with Aid of Novel New Technologies Addressing Sand Production
Authors: Riyami Said , Saadi Faisal , Ghadani Adnan , Palmer Steve , Joy Jerin 
Published: October 2022

Abstract
The effects of uncontrolled sand production can be significant. Many fields are struggling with sand production, which can lead to reduction or complete blockage of well inflow and frequent failures of artificial lift systems such as electric submersible pumps (ESPs) and progressive cavity pumps (PCPs) and thus can have a major impact on cost and production. The currently used mechanical solutions, such as gravel packs or standalone wire wrap screens, are suboptimal because they reduce inflow area and create challenges for any optimization activities. Resins can be effective against sand production but noticeably reduce a well's productivity due to negative effect on reservoir permeability in the critical near-wellbore zone.
The main objective of the work is to improve the run life of artificial lift pumps either ESP or PCP within our cluster which contains multiple fields with different production environments. As percentage during the last 5 years, the statistics of failures showed that about 50% of our failures are related to solids production which are either sand or scale which is about 70-90 wells a year. And based on the chemistry team analysis, sand is the main cause because it can act as accelerating agent for the scale formation.
This paper focuses mainly on the technologies that we used beside the conventional ways and the selection criteria for each of these technologies to mitigate sand production through the pumps. In parallel, we are trialing other technologies to tackle scale.
Initially we started with the actual wells performance in term of failures history and multiple backflush or pump stuck cases within one-year time spam. We took sand sample analysis in form of surface samples to measure the amount of sand produced in g/m3 of liquid and from intervention during the circulation of the fluid.
We will go through the technologies details and the selection criteria that we developed for each of the technologies we used. We used so far 4 technologies which are:
Sand Aid PM filter Sand Guard Cyclone
The details of the technologies and the methodologies that they work by will be illustrated in the paper. There is some specific analysis done for the way to design the technology in such a way to suite the candidate of the well.
A Sustainable Drive in Well Intervention Operations with Case Studies
Authors: Muhammad Salman Saeed , Raza Mustansar , Elmoneim Hossam , Yousuf Arif , Anwar Rameez , Khokhar Saad Yousuf , Temuri Saqib Jah , Ahmed Afnan Dar , Shehzad Kamil 
Published: October 2022

Abstract
Clean out using coiled tubing is the second largest application of coiled tubing after nitrogen kick-off. The advancements in coiled tubing metallurgies to intervene in complex wellbore geometries and precision of downhole simulators to predict on-site scenarios require more efficiencies from end tools that evolved from simple jetting tools to rotating jetting heads. The objective intended in the case studies performed in the Middle East and South Asia was to perform cleanout in scenarios where incumbent tools had failed in the past.
The impact of jetting action in cleanout operations decreases with an increase in stand-off distance. It was confirmed from laboratory tests that a standoff of eight times the orifice diameter and fluid velocity of 200 ft/sec is required to remove moderate to hard deposits from wellbores. Conventional jetting tools have a standoff distance of more than 40 times and fluid velocities are below 200 ft/sec thus objectives are often compromised. A new type of fluidic oscillator was utilized in the case studies discussed in the paper. Unlike pulsating effects created by 1st generation of the fluidic oscillators, the SFO type oscillator had triple jetting action namely, Helix jetting, Pulses Jetting, and Cavitational jetting.
The result of the clean-out with SFO technology was beyond expectations. It saved cost in all the case studies by an average of 35% if had been performed with incumbent technologies and increased production/injection from 30% - to 250% of the original value. Moreover, it reduced the operating times to two-thirds of conventional operations and increased the efficiency of treatment fluids which resulted in the reduction of waste of additives and extra additives to dispose of excess materials at wellsite.
This is the first technology that used cavitational jetting in oilfield services and the first to use aforesaid jetting actions altogether in one tool. The technology adopted in the case studies doesn't have moving or rotating parts, thus eliminating the requirement to pull CT out of the hole for redressing and can perform long operations in one go. It doesn't depend on the centralization of the tool as the jetting effect is passed via kinetic energy through submersed fluids, thus can target deeper depth without limitations of the standoff. It allows a higher flow rate of liquid and gas, thus offering higher fluid velocities to perform an effective cleanout.
Smart Implementation of Asset Integrity Management System (AIMS) at Saudi Armco Khurais Producing Department Facilities
Authors: Al-Boti Abdullah 
Published: October 2022

Abstract
Maintaining assets integrity in oil and gas facility can be quite challenging with conventional ways, therefore a need has arisen for an inclusive efficient way to continuously monitor the critical assets within the plant. Khurais Producing Department (KhPD) in its journey to achieve Operational Excellence has adopted and implemented Asset Integrity Management System (AIMS) for all of its safety critical assets.
The development of KhPD AIMS system has gone through different phases. Starting from identifying the safety critical assets based on approved risk studies and analysis, defining critical functions and performance requirements which the asset shall comply throughout its life cycle as well as linking the system with other inspection and maintenance programs i.e. Preventive Maintenance (PM), Risk Based Inspection (RBI). In addition, a program to continuously assess AIMS was also established to ensure identifying any gaps and highlight areas of improvements.
In this paper, Author will shed light on KhPD experience and share challenges encountered during AIMS implementation by adapting several best practices that helped accelerating the implementation and further enhancing the system. Morover, this paper will share the systematic approach and best practices adopted to overcome the obstacles and challenges in implementing AIMS including the innovative solution of real time, online monitoring and integrated automated alert system as well as the best practice of handling Management of Change (MOC) requirements for critical assets.
Holistic Risk Based Approach to Manage and Control Plant Piping Vibration Through Digital Online Database
Authors: Al Khoujah Khaled , Al Qaydi Juma , Al Mansoori Fatima , Al Blooshi Saeed , McIlwraith Colin , Kaleem Daniyal 
Published: October 2022

Abstract
Processing sour gas requires high care and precautions; it requires elevated levels of steam and other lethal process fluids, which can sometime be present in multi-phase and at high pressure and temperature, resulting in vibrations of different severity, and in such ultra-sour gas plant similar to Shah Plant, developing a robust piping vibration management system is a must to ensure safe operations.
ADNOC Sour Gas has implemented a vibration risk-based approach in-line with Energy Institute Guidelines [1] via a web-based application, so called, Veridian, where the assessment is initiated through a desktop study that targets a review of Piping specifications, Process Fluids characteristics, and mechanical excitation sources within the piping network. Accordingly, a likelihood of failure (LOF) is established which identifies piping systems with a likelihood to vibrate in service, such are nominated for further detailed field measurements and assessment, hence forward, piping systems with actual high vibrations and stresses are shortlisted and reviewed further for solutions and mitigations.
The assessment results in a list of action plans and engineering packages assigned to various responsible, all in a third-party digital database, along with all required drawings, isometrics, PIDs and action details. The system provides users with a facility to look at the details of assessment results and a holistic view of the plant piping network characteristics and vibrations. This paper will present the system developed by ADNOC Sour Gas through utilizing a digital data base designed by Wood Vibrations, Dynamics, and Noise Group. It is worth highlighting that the system has been used previously in multiple other companies and has proven its efficiency in piping vibrations management, specially that it adopts Energy Institute Guidelines.
Deployment of a Novel Soft Sensor in the Real Time Optimizer Architecture to Enhance the Integrity and Energy Efficiency of Sulfur Recovery Units
Authors: Dara Satyadileep , Khan Ibrahim , Al Jenaibi Eisa , Sengupta Subhendu , Goveas Vincent , Al Yahyaee Nawal , Ibrahim Salisu , Jagannath Anoop , Raj Abhijeet 
Published: October 2022

Abstract
Commercial analyzers for measuring the aromatics in the Claus furnace exit gas are currently not available and this leads to sub-optimal energy efficiency and poses asset integrity concerns. To address this problem a high-fidelity model is developed to function as a real time analyzer. Objective of this work is to incorporate the soft sensor in the architecture of Real Time Optimizer (RTO) to monitor the presence of aromatics in the Claus furnace exit stream.
The soft sensor is incorporated in the RTO server which provides the access to the plant operating data and the DCS (Distributed Control System). Soft sensor function in the RTO involves the following steps:
Soft sensor accesses the plant data and collects the needful input data for simulation Simulation software available in the RTO executes the softs sensor model simulation and generates the aromatics composition data Aromatics composition data is written to the DCS interface as a soft measurement Operators monitor the aromatic composition and accordingly adjust the fuel gas firing
Aromatic soft sensor is developed as a kinetic model, which is function of rate parameters of several key reactions of the Claus furnace. The kinetic model of the Claus furnace is incorporated in a process simulation model and catalytic convertors are simulated too. Model is validated with large plant data to show that model predicts furnace temperature within +/- 5% error and aromatics composition within +/- 5 ppm.
Simulation analysis shows that the furnace temperature can be decreased by at least 5 °C while ensuring no BTEX slip. Such change in furnace temperature leads to a reduction in fuel gas flow by ~200 Nm3/h, which translates to a monetary benefit of 0.5 million $/yr. Deployment of the soft sensor is currently in progress through engagement with RTO licensor.
To the best knowledge of authors, currently, there is no simulator in the market which can adequately model aromatics oxidation phenomena and predict the aromatic content in the furnace exit. This soft sensor being deployed is novel and first of its kind and expected to achieve a sustainable energy efficiency.