bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Case of Resin-Based Chemical Sand Consolidation as a Remedial Sand Control Treatment
Authors: Mahardhini Antus , Yudis Putu , Abidiy Izzad , Bawono Yolani , Pradityo Rico 
Published: December 2021

Abstract
The Mahakam delta in east Kalimantan, Indonesia, yields gas as the main hydrocarbon production with giant reservoirs ranging from shallow to very deep zones. Reservoirs consists of clean sandstone with high permeability. Due to the field maturity, production gradually moved from the deep, consolidated zones into very shallow, unconsolidated zones.
Sand production often causes significant problems at the surface when the well is online. The best approach to sand control is to keep it inside the reservoir, because it could create problems not only at surface but within the wellbore as well.
Sand consolidation has been a common approach applied in Mahakam field for more than a decade. Several products have been utilized, including laboratory testing and field trials.
The case history is based on a well that had been treated using 2 different sand consolidation products in the past, but both eventually produced inadequate results. Sand continued to break through after each treatment, hence the reserves could not be drained in full. Since the reservoir still had promising reserves, another remedial sand consolidation treatment was planned. This treatment was executed by utilizing a tension packer with a J-slot mechanism in order to focus injection of the resin into the zone of interest. Additionally, there was a challenge with another open zone above the subject interval. The remedial sand consolidation treatment using a resin-based chemical delivered excellent results. Even though this reservoir had been exposed to 2 different chemical treatments in the past, by using the resin-based sand consolidation product, the well was still able to be produced at target rates without sand production. In conclusion, resin-based sand consolidation solutions can unlock prolific reserves that may have been a significant challenge with traditional methods.
Fracture Height Prediction Model Utilizing Openhole Logs, Mechanical Models, and Temperature Cooldown Analysis with Machine Learning Algorithms
Authors: Khan Abdul Muqtadir , BinZiad Abdullah , Subaii Abdullah Al , Bannikov Denis , Ponomarev Maksim , Parkhonyuk Sergey 
Published: December 2021

AbstractVertical wells require diagnostic techniques after minifrac pumping to interpret fracture height growth. This interpretation provides vital input to hydraulic fracturing redesign workflows. The temperature log is the most widely used technique to determine fracture height through cooldown analysis. A data science approach is proposed to leverage available measurements, automate the interpretation process, and enhance operational efficiency while keeping confidence in the fracturing design.Data from 55 wells were ingested to establish proof of concept.The selected geomechanical rock texture parameters were based on the fracturing theory of net-pressure-controlled height growth. Interpreted fracture height from input temperature cooldown analysis was merged with the structured dataset. The dataset was constructed at a high vertical depth of resolution of 0.5 to 1 ft. Openhole log data such as gamma-ray and bulk density helped to characterize the rock type, and calculated mechanical properties from acoustic logs such as in-situ stress and Young's modulus characterize the fracture geometry development. Moreover, injection rate, volume, and net pressure during the calibration treatment affect the fracture height growth.A machine learning (ML) workflow was applied to multiple openhole log parameters, which were integrated with minifrac calibration parameters along with the varying depth of the reservoir. The 55 wells datasets with a cumulative 120,000 rows were divided into training and testing with a ratio of 80:20. A comparative algorithm study was conducted on the test set with nine algorithms, and CatBoost showed the best results with an RMSE of 4.13 followed by Random Forest with 4.25. CatBoost models utilize both categorical and numerical data. Stress, gamma-ray, and bulk density parameters affected the fracture height analyzed from the post-fracturing temperature logs. Following successful implementation in the pilot phase, the model can be extended to horizontal wells to validate predictions from commercial simulators where stress calculations were unreliable or where stress did not entirely reflect changes in rock type.By coupling the geometry measurement technology with data analysis, a useful automated model was successfully developed to enhance operational efficiency without compromising any part of the workflow. The advanced algorithm can be used in any field where precise fracture placement of a hydraulic fracture contributes directly to production potential. Also, the model can play a critical role in cube development to optimize lateral landing and lateral density for exploration fields.
Holistic Customized Approach to Address Practical Challenges for the Large Scale Implementation of Limited Entry Liners Completions at ADNOC Onshore Fields
Authors: Talib Noor Nazri , Ramarao Subba Venkata , McNeily Kevin , Barragan Ernesto , Maheshwari Yugal , Ahmad Bilal , Abdelhalim Mohamed Emam , Abdelrahim Samy Mohamed , Punnapala Sameer , Al Nuimi Saber Mubarak , Al Taee Arif Saeed 
Published: December 2021

Abstract
Limited entry liners (LEL) implementation strategy is one of the key solutions to to improve the well productivity by maximizing the reservoir contact and matrix stimulation carbonate reservoirs. This strategy requires conducting high rate and high volume acid stimulation with high pressure pump after the installation of limted entry liner, that poses practical concerns to be addressed for adopting conventional well completions and existing resources. In addition, implementation of the LEL completion and stimulation for a large scale application within the minimum time frame and limited resources is a challenge.
This paper provides the detail of challenges faced and solutions adopted to implement the LEL completions amd stimulation at onshore fields. Challenges including suitable candidate selection, completion design, limited materials for well construction to handle high-volume acid stimulation, limited well head injection pressure, contractual limitations for securing the tools and pumping equipment. Further, this paper discusses about the temporary solutions adopted for executing the LEL implementation in the best economical way within near future and provide the long term solutions for LEL implementation in the next 5 years business.
The first three LEL completion wells that were successfully installed and stimulated at ADNOC Onshore are currently producing at more than 2 times higher PI (productivity index) compared to the pre-stimulation rate. The same apply to the injector wells, in which significant improvement on the injection rate of up to 18bbl/min (26000 bwpd) was observed. Currently ADNOC Onshore is planning to execute the LEL completion and stimulation in additional 15 wells during 2021 along with plan for up to 300 LEL completions during the next 5 years. The LEL technology is a key technology to support ADNOC lower completion strategy which aim to minimize the bare foot completions in order to increase the horizontal wellbore accessibility and effective stimulation. Overall, the first LEL installation and stimulation completed within 8 months from the candidate finalization using the existing resources available in ADNOC Onshore.
This paper describes an economical solution for implementation of LEL completion strategy at large scale for major fields within minimum time frame by utilizing the existing resources while adhering to HSE rules.
Agile Smart Completion Application for Effective Water Production Control in Heterogeneous Carbonate Reservoir in Abu Dhabi Offshore Reservoir
Authors: Abdelkerim Ali Issa , Bellah Samir , Ziad Ahmed , Yamamoto Kei 
Published: December 2021

Abstract
This paper provides the learnings from a successful application of a smart completion in a complex heterogeneous carbonate reservoir. It details the study, planning, coordination, and implementation process of two pilot wells by a multidisciplinary team, and pilot production performance results, illustrating the success.
First, to select an optimum completion design for the field, multi-segment well option and local grid refinement option were applied to the reservoir simulation model including calibration of faults/fractures. Second, based on the modified model, sensitivity analysis was conducted; 1) by selecting different types of completion including Open-hole, blank pipes (BP), compartmentalized slotted liners (SL), inflow control device (ICD) and hydraulic flow control valve (FCV); 2) by optimizing the number of compartments (packer and blank pipe placements for all cases), and ICD / FCV numbers and nozzle sizes. Using the data from the modeled cases, economic analysis was conducted, which indicated that the ICD in conjunction with sliding sleeves (SSD) was the best option.
Two candidate wells were selected to cover the variation of reservoir characteristics: one well representing the heterogeneous part of the reservoir with high-density of faults, fractures and kurst, and another one representing the relatively homogenous part of the reservoir suffering from heel to toe effect. A multidisciplinary implementation team was set up to align all stakeholders on subsurface requirements, following up the completion design, coordinating material procurement and logistics for mobilizations, daily drilling operations follow-up, real-time logging data interpretations and completion design adjustment.
Evaluation of the two pilots’ results based on predefined KPIs during the study, exceeded overall expectations.
Firefighting Drones - A Safer & Efficient Technology to Confront Industrial Fires
Authors: Almughani-Alnaqbi Mohamed Abdalla 
Published: December 2021

Abstract

Objectives/Scope
This paper presents the variety of possibilities that this new technology can offer and how we can apply those technologies to optimize our HSE and take preventive measures that will be economically and humane solutions to crises. New technology, including Artificial Intelligence & Robots, does not necessarily mean it will replace human jobs and human judgment but will be used as tools to minimize hazards in critical situations and helps to solve the problems in a faster and efficient way.

Methods, Procedures, Process
The recommended technology to fight fire in hazardous zones can be described as a “firefighting drone.” This drone can be considered a faster and safer approach for fire suppression that can respond to any fire alarms and fly in narrow places inside the live plant, crude oil storage tanks, and navigate quickly to exact fire location without any fear of crashing it to anything and eliminates the risk of reaching high rise buildings where it is not secured and has low visibility.
One such method is a firefighting drone that carries fire extinguisher balls, where it mainly consists of dry powders that contain melamine phosphate as an extinguishing component. This extinguishing ball works as a fire auto hydrant that is attached to the drone.
This mechanism helps the drone carry the fire extinguisher balls to any place and throw the ball into the fire to suppress it. The main advantage of such fire extinguisher balls is its lightweight comparing to water, and it is environmentally safe and harmless to the human body if used in hazardous zones such as oil and gas plants.

Results, Observations, and Conclusions
Studies show that fire extinguisher balls have high extinguishing effectiveness and serve a wide range of applications. Results show that around 0.5 kg ball size has the ability to extinguish a 1-meter radius.
This paper explains how easy its to build such a drone. However, due to the nature of this application using thermal resistance material is a must, and utilizing Artificial Intelligence will enhance the drone capabilities & will help to improve firefighting methodology. This type of drone is designed to be used in very high-temperature conditions and can be controlled safely from a ground station manually where you can see the fire location and assess the situation without the need to be there and wait for the fire team's presence.

Novel/Additive Information
With the use of the new lightweight fire extinguish ball, we can enhance the typical current firefighting method for small and medium-scale fire, where it puts out the fire faster & help us prevent it from growing to a more significant fire.
The ultimate goal of this drone is to save the life of firefighters, plants, and equipment. Since the oil and gas industry is of high importance in the UAE, using proper and enhanced HSE measures will maintain our assets and avoid crises that will have a massive impact on business continuity.
Challenges of Gas Wells Killing Operation with Emphasis on Reservoir & Completion Integrity Issues
Authors: Ahmad Zeeshan , Al Hosini Abdullah Alhaj , Al Janahi Mohammed Ibrahim , Al Marzouqi Abdulla Mohammed , SIDDIQUI Muhammad Ali , Al Zarouni Abdulla Haidar Abdulla , Ansari Saad Wajih Uddin 
Published: December 2021

AbstractWell killing always remains a most radical part during the life cycle of gas production wells with reservoir and completion integrity issues. In moderate permeability gas reservoirs, it will be more challenging due to below issues;Low pressure gas reservoir with moderate reservoir permeability where hydrostatic head of water is almost double the formation pressureWell with the sustainable annulus pressures (Production & first cemented annulus) Well with complex layered scale / asphalting deposition Completion jewelry component integrity breached Recycle reservoir with pressure maintenanceNoise logs / corrosion logs generally conducted in order to assess the downhole completion jewelry and potential leak source prior any attempt for killing the well. To achieve the desired accessibility extensive scale analysis for better designing of scale clean out operation carried out specially to access the SPM. Variation of reservoir permeability considered for designing of optimized kill fluid for Depleted horizontal gas reservoir to cater challenge of complete losses. Effective fluid loss solutions designed and implemented to avoid abnormal fluid losses. Further more Polymer based gels used to kill and prevent the gas peculation to surface.Wells having completion and reservoir integrity issue isolated by considering cement zonal isolation, salt plugs, thru-tubing bridge plugs and nipple less plugs. All these barriers having their advantages and disadvantages with reference to work over objectives and their application limitations with respect to well conditions and detail study conducted for each candidate prior execution.Depletion Gas well killing and securing operation considered to be complex in nature and may result serious concern of rig intervention or well future objectives in case of improper execution. Gas wells having reservoir integrity issues and in case of 1st cemented Annulus pressure can be isolated by using thru-tubing bridge plugs. For retrieval of dummy from SPM must be done after setting of downhole plug to avoid any heavy suction for wire line operation. Cement plug operation is not suitable for such wells due to severe losses and fluid circulation limitation. Adequate selection of kill gel fluid as per reservoir characteristics will improve the killing efficiency.
A Case Study on Project Realization Digitalization from the Domain Perspective
Authors: Mohd Azmi Nurul Aminah , Veroba Grant , Zainalabidin Muhammad Aizuddin 
Published: December 2021

Abstract
This paper provides a Case Study in Front End Project Realization digitalization from the Domain perspective, with a focus on the methodology used, process enhancements that were enabled through automation, and lessons learned during the transformation.
The transformation has been an iterative process, first focusing on digitalizing modules within the Front End work process and evolving into a multi-discipline integrated digital application. Along the journey, application of Agile project strategies enabled continuous enhancements to be identified and implemented through lessons learned, formal design thinking reviews, new idea generation and informal engagements with other disciplines commencing their digital journey. The process enhancements include: New Ways of Working to seamlessly integrate Front End technical and cost analytics engines, and across broader enterprise digital Field Development processes.New Sources of Insight to expand ideation using cross industry learnings, maximize use of extensive internal project data, and embedded Best in Class benchmarking.
The Front End digitalization process identified significant value to stakeholders through increased pace of delivery, improved early concept definition with limited human intervention, increased cost accuracy, and increased confidence in the results through replication, improved data supply and benchmarking rigor. Specific value unlocks are seen across Front End Loading (FEL) i.e., pre-FEL to FEL-2 stages and will be presented. Through incorporation of enhanced data and insights, improved cost compression and decision-making quality has also been identified and subsequently will improve the project economics.
A number of challenges through the transformation process were identified. These included: integration or replacement of legacy technical and cost applications; identifying and digitalizing a wide range of internal engineering tools and data sources needed for a comprehensive digital Front End process; efficiency of translating technical requirements to the digital team through comprehensive mapping of design and experienced-based rules; and re-shaping Front End technical focus from deliverable generation to targeted assurance, value obsession and risk management. While major focus has been on the integration of internal technical and cost applications, significant challenges were also identified in integration of external applications and Application Programming Interface (API) readiness to allow interaction between the applications and the Front End digital application i.e., Concept Factory. And finally, challenges in achieving a high performance team with the right balance of Domain, translators and programmers will be discussed.
IOT Technology Demonstration in ADNOC Onshore Fields. Real Time Monitoring at a Minimum Cost
Authors: Liebeck Martin , AlShehhi Shamma , Hariz Mohammad , Hammadi Khaled Eissa , Camacaro Alfredo Eduado Freites , Al Baloushi Mahdi Abdulla , AlShmakhy Ahmed , Salamitou Philippe , Gambier Philippe , Villegas Humberto , Bertone Javier 
Published: December 2021

Abstract
In brownfields, controlling well integrity is critical in maintaining production and ensuring safety of the personnel and infrastructures. Equally important is optimizing and allocating production in wells by closely following wellhead upstream pressures (and temperatures). In the current situation, field crews have to move from well to well. This method is time consuming, exposes personnel to driving hazards and potentially dangerous areas. In addition, human reading of manual pressure gauges can result in large discrepancy in the reported values. Together with the low frequency of manual readings, this method does not allow for pro-active well intervention and can result in higher downtime in case of well tripping. Deploying remote monitoring with classical telemetry in fields with limited telecommunication infrastructure is costly and complex.
Low Range Wide Area Network (LoRaWAN), a public wireless network technology developed in 2009, changes the situation. It enables low power compact battery sensors with up to 10 km radio range. This performance is sufficient to connect, in one go, most onshore wells without power nor connectivity.
This paper describes a pilot project to evaluate the adequacy of this technology in ADNOC Onshore fields. The objective is to assess performance of LoRaWAN deployed Sensors along four metrics: deployment time, deployment cost, Base station radio coverage and data availability. The pilot uses a plug-in ATEX- certified Wireless Pressure and Temperature (P&T) sensors developed by the vendor SRETT, commercial LoRaWAN Base stations, and proprietary software to provide remote access to the data via cloud data storage and web based application.
For this pilot, four Base stations were deployed in two giant oil fields collecting data from four well heads each equipped with two sensors (P&T). This combination allowed testing wireless link quality over eight radio paths, some with terrain obstacles between Sensors and Base stations. The complete system was fully tested and validated at the shop prior to field deployment. Performances during the deployment was evaluated, and Sensor behaviors were monitored over a three-month period.
In the current environment, maintaining a high HSE standard on aging infrastructure must be made at a controlled cost. LoRaWAN IoT remote monitoring technology is cost effective and efficient to deploy. Once deployed, it will enable preventative safe detection of wells with potential issues, improved accuracy and understanding of production events and lead to a reduction of potential adverse situations thanks to an optimized intervention strategy.
Geochemical Techniques to Detect Sources of Fluids in Highly Pressured Casing-Casing Annuli CCA
Authors: Birkle Dr. Peter , AlRamadan Hamdi A. 
Published: December 2021

Abstract
The buildup of high casing-casing annulus (CCA) pressure compromises the well integrity and can lead to serious incidents if left untreated. Potential sources of water causing the elevated CCA pressure are either trapped water in the cement column or water from a constant feeding source. This study utilizes inorganic geochemical techniques to determine the provenance of CCA produced water as trigger for high pressure in newly drilled wells. Affinities in the hydrochemical (major, minor and trace elements) and stable isotopic (δ2H, δ18O) composition are monitored to identify single fluid types, multi-component mixing and secondary fluid alteration processes. As a proof-of-concept, geochemical fingerprints of CCA produced water from three wells were correlated with potential source candidates, i.e., utilized drilling fluids (mud filtrate, supply water) from the target well site, Early - Late Cretaceous aquifers and Late Jurassic - Late Triassic formation waters from adjacent wells and fields. Geochemical affinities of CCA water with groundwater from an Early Cretaceous aquifer postulate the presence one single horizon for active water inflow. Non-reactive elements (Na, Cl) and environmental isotopes (δ2H, δ18O) were found to be most suited tools for fluid identification. 2H/1H and 18O/16O ratios of supply water and mud filtrate are close to global meteoric water composition, whereas formation waters are enriched in 18O. Elevated SO4 and K concentrations and extreme alkaline conditions for CCA water indicates the occurrence of minor secondary alteration processes, such the contact of inflowing groundwater with cement or fluid mixing with minor portions of KCl additives. The presented technology in this study enables the detection of high CCA pressure and fluid leakages sources, thereby allowing workover engineers to plan for potential remedial actions prior to moving the rig to the affected well; hence significantly reducing operational costs. Appropriate remedial solutions can be prompted for safe well abandonment as well as to resume operation at the earliest time.