bluuebunny/crossref_metadata_2025_split huggingface dataset:
Management of Facilities Services Across ADNOC Group Companies
Authors: AlMazrouei Mouza , Ahmed Reda Hashem , Muckattu Joseph 
Published: October 2023

Abstract
ADNOC Group B&S managing its facilities across ADNOC Group Companies by planning, executing, and monitoring all facility services involved in building maintenance services, office space management, building asset management, and soft services by using Computer Aided Facility Management (CAFM) system.
CAFM system is a specific type of facility management system that allows users to optimize a lot of customer-oriented services in an organization, such as facilities services, office space management, building assets management, and so on. Additionally, CAFM system allows for planning, executing, and monitoring of various activities within facilities once the building is ready after construction handover.
ADNOC Group B&S is adding Service Provider contracts in the system and managing Service Providers operational scope of work such as Assets, Buildings, Resources, Maintenance Schedules, Spare-parts, Service Level Agreement (SLA) and Key Performance Indicator (KPI).
Also, CAFM System h a s mobile solution which enabled ADNOC Group B&S to facilitate the Service Provider to perform real-time maintenance activities and allow business owners to monitor the Service Provider work-orders/service requests.
One of the important tools that enable ADNOC Group B&S to have a visualization of information is by utilizing the Data Analytics and Business Intelligence dashboards.
Improving Process Control Performance in Project Delivery
Authors: Al Mawali S. , Al-Sibani O. , Moosawi M. , Alawi A. 
Published: October 2023

Abstract
This paper discusses the challenges of ensuring effective process control performance in new projects in the oil and gas industry. It also presents Petroleum Development Oman's (PDO) approach to incorporating process control into project delivery to address these challenges. PDO has improved process control performance in new projects by adopting a comprehensive approach. This approach includes introducing KPIs, establishing a process control discipline, and updating the company's quality assurance framework. The results of these changes have been significant, with two mega projects achieving a higher process control performance than previous projects of comparable complexity. These improvements ensure that the value of a project is reaped as early as possible in the operate phase directly after commissioning and handover and thereby maximizing the return on investment for automation.
Challenges and Mitigations in Geosteering the Longest 6 1/8 Inch Horizontal Reservoir Section in Adnoc Onshore History
Authors: Chikhi Zoheir , Abdulla Al Hosani Fatima , Yousif Al Blooshi Mariam 
Published: October 2023

Abstract
This paper is about the Geosteering challenges and mitigations in drilling the longest MRC well in Adnoc Onshore history. The well was drilled as Horizontal Oil Producer with the objective to maintain current sustainable production in Habshan-9 (R1_B) formation based on the new ADNOC approach to drill MRCs (Maximum Reservoir Contact) in Abu Dhabi fields. The MRC philosophy has been implemented in Adnoc Onshore for many reasons, mainly to deal with the surface congestion and the anti-collision in the subsurface. This paper presents the challenges faced in planning and drilling of the subject MRC well with a total measured depth of 28,200ft (8.5km) and having horizontal hole of 17,148ft (5.23 km reservoir contact).
The planning phase was crucial to align all stakeholders (reservoir management team, subsurface operations, drilling, material, fluids, completion and directional) on the common objective of delivering safely and as per the objectives the longest 6 1/8-inch horizontal reservoir section in Adnoc Onshore history. The meetings were meant as well to mitigate all the associated risks by proper planning of the drillability analysis, the agreed trajectory, collision risks if any, BHA choice, hydraulics, logging tools and choice of the lower completions. The well was more challenging as it is drilled up dip the thin (2-4 ft) Habshan-9 (Habshan-1) formation.
This paper will explain the way the landing inside the thin Habshan-9 reservoir was achieved and how we maintained a very smooth hole with a DLS (Dogleg Severity) &lt; 1 deg/100 ft. indispensable to run a +17k LEL (Limited Entry Liner) lower completion.
This Oil Producer MRC well is the longest 6 1/8-inch horizontal reservoir section in Adnoc Onshore history unlocked the potential to drill even longer wells which will significantly improve well performance, enhance the reservoir management, reduce the field development cost and reduce the field congestion.
This paper summarizes the challenges encountered during the geosteering and the mitigations that allowed successfully complete and deliver the longest 6 1/8-inch horizontal reservoir section in Adnoc Onshore history.
Comparison of Cement Evaluation Utilizing Different Logging Tools and Cementing Best Practices: A Case Study in Middle East
Authors: Nathan Kumar , Kamarudin Muhamad Aizat , Devadass Lingges , Mohammed Mustafa Jawad , Yen Kok Kwi , Amat Hadi , Choon Tan Boon 
Published: October 2023

Abstract
Cement Evaluation Tools are usually deployed to evaluate the cement bond behind the casing or liner prior to well test or produce the well. Since oil and gas spillage can be hazardous to environment and impose great HSE risk, the cement evaluation is often given a special priority especially after the Macondo incident. Hence, in many countries the regulatory authorities have imposed a strict requirement on having good hydraulic isolation before letting the well to be tested, produced, or abandoned. Thereby, cement evaluation logs become the necessity to be run in all the wells to analyze the cement bond behind the casing.
The basic cement evaluation log which is cement bond log (CBL) is being around and well understood by the industry and still being used as a basic log concurrently with other advanced logs. High demand on the cement evaluation logs makes the cement evaluation tools to undergo tremendous development and with better understanding on the physics of the measurement, industry players have developed various tools. The cement evaluation tools can be categorized into broad category of acoustic based, ultrasonic based, radioactive based and electromagnetic based logging tools. Among all these cement evaluation tools, ultrasonic based tools are the mostly used tools in the industry. In line with the advancement of the tool, the efficacy of cement evaluation will only be maximized when the cement evaluation procedure and technique are simultaneously improved. Additionally, the improvement on the cementing procedure and cement recipe shall also be performed from time to time based on the actual cement bond evaluation result for optimum cement bond behind the casing.
Hence, this paper will give a comprehensive view on the cement bond assessment done in Field G from basic to advance cement evaluation tools. This includes the factors that affecting cement quality which includes both the logging operation, and cementing procedures. The interpretation technique and guideline that were developed to evaluate the cement bond behind the casing will also be discussed. The cement evaluation data analysis from 120 wells from Field G will not only aid industries in selecting appropriate logging tools and cementing procedures for cement evaluation, but wit will also serve as an avenue to give new perspective in logging and cementing operation.
India's 1st Polymer Flood Scheme Implementation from Laboratory to Field in Heavy Oil Having Strong Aquifer
Authors: Sharma Ajay Kumar , upadhyay Sandeep , Mitra Sujit , Meena Rakesh , Mavoori Ravi. S. 
Published: October 2023

Abstract
The case studies for Polymer flood globally in heavy oil are few and far between. The low primary recovery of this field warranted an EOR scheme. The present paper discuss the challenges in designing & implementing a polymer flood project in a heavy oil field in a strong aquifer drive with vertical well configuration. The paper covers a complete EOR cycle from screening, laboratory studies, simulation studies, pilot execution and further full field implementation.
EOR screening was carried out through established screening methods to find a suitable EOR technique. Post screening, polymer flooding was tested in the laboratory and based on the encouraging laboratory findings, it was recommended for simulation studies. Sector modelling with fine grid scale of 16*16m carried out for pilot simulation study. Polymer Pilot scheme was designed and successfully implemented in the field in May-2019. After Successful pilot execution, history match of the polymer pilot was carried out. Learning's from the pilot study were incorporated in the model and full field scheme was implemented in the field in Oct-2022.
Thermal stability tests for various polymers were carried out in laboratory and thermally stable polymers were shortlisted. Similarly, test for adsorption and screen factor was carried out and suitable polymer was shortlisted for core flood experiments. Core flood experiments carried out on sand pack made from native sand of the reservoir. Based on the mobility ratio and shear thinning properties of selected polymer, polymer viscosity was taken as 25cp. Polymer flood linear core displacement efficiency was found 61.4%. Incremental displacement efficiency was 17% over water flood.
After laboratory experiments simulation study was performed for polymer pilot. Sensitivity carried out for number & type of patterns, pilot site, injection/production rates, residual resistance factor (RRF) and pore volume injection. Based on simulation results a normal 5 spot pattern was proposed for field execution. Envisaged incremental recovery over base case was ~12% of target oil. Expected oil recovery was achieved in pilot and water cut reduced from 80% to 60%. History match of pilot was carried out in the black oil simulator. After pilot history match full field scheme was prepared and implemented in the field in Oct-2022.Incremental recovery envisaged in full field scheme over base is ~ 5%.
This study has proved that polymer EOR can enhance oil production in heavy oil with strong water drive. This project paved way forward for other analogous fields. A standard methodology was adopted to implement polymer flood in all analogous fields of the company with low recovery. The experience and expertise gathered from this study has given courage to implement full field polymer EOR in analogous fields without pilot study.
Chemical Tracer Evaluation of First Horizontal Multistage Fracturing Treatment Well in the Telisa Formation, Indonesia
Authors: Yudhanto G. , Pramadana A , Akbari A. , Gani E. E. , Koseluk D. , Harjaya B. , Makmun A. , Swarnanto A. 
Published: October 2023

Abstract
Efficient hydraulic fracturing is one of the most important parts of Telisa formation development strategy. Historically, the Telisa formation was developed with single-stage vertical wells, stimulated with conventional propped hydraulic fracturing technique. To promote field development, operators looked for drilling horizontal wells completed with multistage hydraulic fracturing treatments. Aiming to evaluate the effectiveness of new well completion method, non-invasive and cost-effective diagnostic evaluation tool was needed.
Chemical tracers have been used for many years to understand the effectiveness of hydraulic fracturing operations by utilizing unique chemical tracers in each stage (or stage grouping) to provide an understanding of relative tracer flowback contribution. Tracer contribution can be affected by several variables, including reservoir quality, effectiveness of the hydraulic fracturing treatment, and areas of pressure depletion from existing offset vertical or horizontal wells. Liquid-water chemical tracers provide an understanding of far-field, hydraulic-fluid movement, while solid particulate oil and water chemical tracers provide an understanding of near-wellbore connectivity with created hydraulic fracture. When using both tracer types in combination, a more comprehensive understanding of the hydraulic stimulation can be attained.
This paper will discuss the general characteristics of the Telisa formation and how the design of hydraulic fracturing treatment was implemented. The chemical tracer design will also be discussed, and the chemical tracer results will show how the unique characteristics of both solid particulate and liquid chemical tracers were used to provide a detailed understanding of stage performance after the successful implementation of the first multistage horizontal well in this field.
The data from the solid particulate chemical tracer recoveries were used to show the effectiveness of each stage in the hydraulic fracturing treatment. The liquid water chemical tracer recoveries helped to identify stages in the well where pressure depletion from nearby vertical wells might have affected far-field fracture fluid movement. All the data gathered during this study will be valuable in the future development of the field as more horizontal and multistage wells are drilled and completed.
Reducing Embodied Carbon by Using Fibre Reinforced Polymers (FRP) Rather Than Steel
Authors: Eves S. , Lye N. , Herbert B. , Chiu A. , Friedrich R. 
Published: October 2023

Abstract
In recent years embodied carbon has become an important consideration when designing and specifying new builds and refurbishments in the oil and gas industry. Fibre Reinforced Polymer (FRP) structural products and Glass Reinforced Epoxy (GRE) pipes have been used for a number of years due to their light weight and corrosion resistant properties, but these properties also have the effect of reducing the embodied carbon of the products over their life span. Reduced transport weight, reduced maintenance and longer lifespan are all contributing factors. By taking the examples of traditionally steel products and their FRP equivalents this paper aims to quantify the potential savings.
The comparison for structural products focuses on Multi-Angle Rapid Railing System (MARRS™) offshore handrails manufactured with FRP profiles and fittings (MARRS FRP handrails) vs. Galvanized Steel Handrails. For GRE pipes, a typical 12-in. pipe is compared against steel alternatives. This study uses baseline scenarios to calculate the main life cycle impacts and scenario-based analysis to account for the maintenance and repair opportunities that the products allow for. Global warming potential is the impact category analyzed in the study.
A typical MARRS handrails installation could be 4,000 linear meters, meaning the embodied carbon for the steel handrail could be as high as 5,500 tonnes of CO2e, while the MARRS equivalent will be less than 200 tonnes of CO2e, a saving of over 96%.
The use of GRE pipes in place of traditional CS pipes produces at least 60% savings over 20 years, with further savings from the embodied carbon used in work required to install replacement pipes due to corrosion.
Predicting EOR Polymer Viscosity with Varying Molecular Weight and Chemistry Using Machine Learning
Authors: Maillon Rémi , Ghosh Pinaki , Wilson Clayton 
Published: October 2023

Abstract
Polyacrylamide polymer flooding is an established EOR technique to reduce the water/oil mobility ratio and improve sweep efficiency. Polyacrylamide polymers are non-Newtonian fluids whose viscosity depends significantly on shear rate in addition to several other parameters, such as brine salinity and hardness, temperature, polymer concentration, chemical composition, and molecular weight. Each oil reservoir has unique brine compositions, expected shear, and temperature conditions. Estimating the polymer solution's in situ viscosity under these conditions can be quite challenging, requiring expensive and time-consuming rheological lab experiments.
Machine learning has recently gained popularity and has been applied successfully in many sectors, including the oil & gas industry, to develop predictive models and forecasting tools. With more than 30 years of experience in polymer EOR projects globally, SNF has compiled a large rheological dataset, including approximately 75,000 lab experiments measuring the viscosity of its synthetic polymers under different reservoir conditions. In this study, different machine learning algorithms have been tested on SNF's rheological dataset to predict polymer viscosity for any given polymer type and concentration under certain reservoir conditions. The best results were achieved using a Random Forest algorithm, the results of which have been presented here. The model predictions are based on the following eight input features: active polymer concentration, shear rates, brine total dissolved solids (TDS), hardness, temperature, polymer molecular weight, and chemistry (ATBS percentage and Acrylamide percentage). Based on preliminary investigations, the results obtained are promising, with an R-Squared regression score of 89.6 % and a mean absolute percentage error of 35.8%.
The model's results have helped SNF better understand the impact of these different parameters on polymer viscosity and can be used for improved quality control of lab measurements generated across the globe. This tool aims to aid product development by providing in silico data in concurrence with in situ experiments, driving a robust development process.
Matrix Stimulation in Heterogenous Carbonate Reservoir: A Case Study from the UAE using Custom Acidizing and Self-Diverting Acid Treatment as an Alternative to Conventional 15% HCl Treatment
Authors: Tuoyo Ella , Ambrosi Giuseppe , Hernandez-Solana Leticia , AlKamali Mathayl , Ottolina Renny , Akl Osama G. , Alshehhi Hajer 
Published: October 2023

Abstract
This paper aims to highlight how important it is to apply the matrix acidizing engineering approach to achieve the best results for any well, which includes the custom chemistry selection and execution procedure to enhance well productivity in argillaceous limestone reservoirs. This study showcases the complexity of interaction between the various layers of the reservoir and the self-diverting agent, and how this optimized placement leads to increased treatment effectiveness.
Using 15% Hydrochloric Acid (HCl) on carbonate reservoirs is challenging due to the speed and aggressiveness of the reaction. In addition, there is no doubt that in matrix stimulation the diversion and coverage of the treatment fluid plays a key role in driving the efficiency and final result of the operation. For this case study a customized acidizing blend combines primary and secondary reactions that provide longer reaction time and better etching. In addition, a pH-activated self-diverting acid was pumped in stages to provide dynamic diversion of the treatment fluid while being pumped.
The well is a newly drilled, open-hole, single gas producer in a green field. Apart from the already listed benefits, other considerations were the natural fractures in the reservoir, the high percentage of swelling and migrating clays in some zones, and the long treatment interval.
The original treatment was designed considering four (4) stages (2 acid and 2 self-diverting acid system stages) and 20 gal/ft of reservoir. After the 3rd stage, the well recorded a peak of 12 MMscfd of gas (the objective was 8 MMscfd), and the Wellhead Pressure (WHP) surpassed 4,500 psi, which created some operational concerns since the wellhead was only rated to 5,000 psi. Based on this, a decision was made to cancel the 4th stage of the treatment and open the well to reduce the pressure quickly. However, as the horizontal section is open hole and was recently treated with acid, this abrupt change in reservoir mechanics led to a suspected collapse of the formation.
The stimulation approach proved successful during the operation as post-job analysis of the wellhead pressure response indicates a significant skin reduction. The results, however, brought conditions never seen before in the area, and the contingency steps taken proved detrimental to the reservoir.
Following the correct matrix stimulation engineering approach helped to select a custom solution for the well that considered the proper reaction time of the treatment chemical systems with the reservoir. This improved the creation of the wormholes and determined the diversion technique to consider maximizing reservoir coverage over the length of the open hole section.
Well Hookup Surface Completion Optimization
Authors: Al-Mawali M. , Al-Hasni R. , Al-Abri A. , Al-Barwani M. 
Published: October 2023

Abstract
In the Oil & Gas upstream industry, the efficient and timely installation of well hook-up surface equipment's holds a vital importance for ensuring safe and productive operations to ensure an immediate return on investment. It is crucial to minimize the time and risks associated with bringing the well hook-up surface scope into production after a rig move off location. This paper introduces an integrated approach that focuses on achieving a safer design, cost optimization and minimizing installation time as well as the flexibility of the designed system, ultimately aiming to expedite the production of the first drop of oil.
The petroleum industry operates in a highly competitive and fast-paced environment, where every minute counts. Following the rig move, the installation process of the well hook-up surface scope must be completed promptly to resume production activities and avoid potential financial losses. Consequently, exploring innovative approaches that streamline the installation process and mitigate associated risks becomes crucial.
The integrated approach proposed in this paper represents a comprehensive and strategic solution to address the challenges encountered during the installation of well hook-up surface scopes. By incorporating advanced technologies, meticulous planning, and optimized procedures, this approach aims to maximize operational efficiency and minimize costly delays.