bluuebunny/crossref_metadata_2025_split huggingface dataset:
Drilling and Cementing Through Highly Active Shallow Gas Field
Authors: Alfakih Abdulqawi , Galaby Amir , Sadiq Nauman , Famiev Robert , Nafi Mohammed Khalil 
Published: October 2022

Abstract
Drilling and cementing through surface sections with highly active shallow gas formations is seriously challenging. In order to save employees lives and maintain a safe working environment, wells are designed with careful consideration of mud weight, drilling and mud parameters, while utilizing advanced monitoring techniques during well execution. While drilling, if well flow situation occurs, killing the well using industry accepted killing methods is not always possible as proper blowout prevention systems are not yet installed at the wellhead. For such wells, a diverter system must be utilized, enabling closing the well and diverting the flow to a safe distance away via two large sized vent lines for the rig crew to evacuate the work area safely. In cases where shallow gas contains flammable hydrocarbons, evacuation is mandatory. In some places in the Middle East however, the shallow gas has different properties, being inert nonflammable Nitrogen (N2) gas, eliminating both explosion and fire risks. Nevertheless, handling high pressure blowouts introduce severe risks to crew members, equipment, and the environment. In case drilling is decided to be initiated in the high-risk shallow gas area, all precautions must be taken to prevent gas flow whilst drilling. This is possible by adequate mud weight selection allowing sufficient overbalance throughout the complete drilling, casing, and cementing operations ensuring shallow gas zone is properly sealed and isolated before drilling deeper intervals.
In a large Middle East field, a large number of wells have been drilled with some areas having shallow nitrogen (N2) gas at high pressure in formations lying at 200-800 ft depth. In such areas, having shallow N2 gas flow is inevitable. Due to the limitation of surface locations, and in order to develop all field recoverable reserves, the only way is to drill wells in the highly active shallow N2 gas areas. The field is developed by drilling costly horizontal multilateral wells with maximum reservoir exposure. Wells typically start by drilling two large sized surface sections, a 28-in which extends to +/-160 followed by a 22-in wellbore sections. While drilling the 22-in section only extends to +/-1200-1800 ft, however, multiple drilling challenges have been observed as a result of the presence of a highly active shallow N2 gas formation. Gas influx while drilling, well flowing and gas channeling after cementing, and continuous gas bubbling in the cellar represent the main challenges experienced in the 22-in surface section.
This paper will present details of the engineering analysis performed and the procedure developed to enhance well design and cementing through the highly active shallow N2 gas surface section.
Safer and Faster Drilling through AI Driven Permanent Cuttings Monitoring - An Operator's Approach
Authors: Ripperger Georg , Peisker Jörg , Oberschmidleitner Patrick , Kucs Richard Josef Werner , Winkler Doris 
Published: October 2022

Abstract
Having the ability to study the solid cuttings separated on the shale shakers can provide valuable insights into hole cleaning, state of the drill bit, mud and shaker performance and potential damages to downhole equipment. Although studying the lithology of the cuttings can serve as first visual confirmation of formation changes, cuttings volumes allow judgement of hole cleaning and assess whether wiper trips are needed or can be avoided. Cavings on the other hand, can be a first indicator for problematic wellbore stability conditions and can be used to stay out of costly kick situations. Despite this potential of vital information, shakers are rarely equipped with sensors. The equipment is monitored manually by field personnel and material samples are taken only discontinuously. This in return poses a high risk in receiving information too late to react to or miss it altogether.
The operator believes that closing this gap is a crucial factor for drilling automation and optimization and that this can be done best by real time video analysis. Apart from cuttings volume flow and cavings detection, the operator, deemed an additional benefit in demonstrating in-house capabilities in the field of machine learning (ML). The ease of internal data accessibility in combination with a small overhead was key for a fast and thus cost-efficient development.
The project presented in this manuscript, was executed using multiple machine learning models trained in-house that proved the concept of providing average cuttings size and sieve coverage in real-time from a video source. Subsequently, the operator built a test stand and conducted a series of static and dynamic experiments using regular, LIDAR and stereoscopic cameras. The learnings from the laboratory work were applied in an additional test series on an onshore rig to validate the laboratory results under field conditions. Ultimately, the scalability of the proprietary ML model was tested with video samples from already installed equipment on drilling rigs.
The project successfully demonstrated the feasibility of using deep learning and machine learning approaches to introduce camera-based solids monitoring to the drilling industry. Despite the fast development time, it was possible to successfully recognize cuttings, cavings and anomalies in the solids output using proprietary machine learning models and regular off-the-shelf hardware. The acquired data will be used to calibrate simulations and monitor deviations between modelled and actual data in real-time. Based on the excellent technical feedback, economic value of the underlying business cases and fast-track in-house development, pilot projects are in the pipeline to lift these new tools to the next technological readiness level.
Improving Drilling Performance Using Drilling Efficiency Optimization (DEO)
Authors: Al Braiki Abdullah , Taha Ahmad , Al Rubaiey Hilal , Al Naabi Hashil , Al Lawati Yasin , Al Subhi Anees , Al Hinai Qasim , Radwan Mohammed 
Published: October 2022

Abstract
Petroleum Development Oman (PDO) is the leading Exploration and Production company in The Sultanate of Oman, and it delivers the majority of the country's crude oil and natural gas supply. It also has a great focus on delivering excellence, growth, and sustainable value creation within and beyond the Oil and Gas Industry. It is a pioneer in adopting state of the art technologies to run its business and to even goes beyond the Oil and Gas industry by supporting the nation in capability building and sustainable development. This is but an implementation of Petroleum Development Oman's Vision which is to be renowned and respected for the excellence of our people and the value created for the Sultanate of Oman and all the stake holders.
With the heavy focus from the world in the recent years on Digitalization and Transformation, Petroleum Development Oman has set its sails in the Digitalization journey by creating a dedicated team that supports the company's business through digitalization. With the focus on Digitalization comes the utilization of Artificial Intelligence. The driver behind this focus is to have an increased efficiency, achieve greater business agility and creating value for the business in an environment where the oil price is highly volatile.
In the Oil and Gas industry, drilling performance is key to reduce the overall cost of the well construction. Different companies strive for performance improvements through many ways that include technology, optimization and recently, digitalization. Automating the Drilling Efficiency Optimization (DEO) is one example of applying digitalization in the Oil and Gas Industry. DEO is a tool that was developed over the years to suggest the optimum parameters that lead to optimum performance based on historical data. In the past, the DEO Roadmap construction was done manually. It was time consuming and had limits when it comes to amendments as the data can be updated only after drilling a well. Nowadays, Petroleum Development Oman has managed to automate the construction of the DEO Roadmap and allow it to be updated continuously in a feedback loop using data mining and Artificial Intelligence.DEO is now set to process over 500 wells every year with a target to improve and optimize drilling efficiency.This has led to improvements in people's efficiency as it takes less time to view the roadmap. DEO was piloted in of the deep wells where hard rock is drilled and It led to improvements in the drilling performance where savings as high as $430,000 per well were achieved.
Single Trip Multizonal Resin Sand Consolidation and Fracturing, A Novel Technique in Sand and Fines Control
Authors: Rozlan M Rizwan , Salleh Nurfarah Izwana , Magna Bela Sunanda , Misron M Al Perdaus , Kumar Suman 
Published: October 2022

Abstract

Objectives/Scope
An Unconsolidated Near Wellbore (NWB) area of the formation as well as the high fines content in the formation have led to massive sand and fines production and therefore, Loss of Pressure Containment (LOPC) at surface facilities. Resin sand consolidation to strengthen the NWB area and fracturing to immobilize fines during production are necessary. However, performing both resin sand consolidation and fracturing completions in multizonal reservoirs is too costly. Therefore, a single trip multizonal sand consolidation and fracturing job is performed to reduce operational days and cost

Methods, Procedures, Process
Three (3) different techniques to perform resin sand consolidation and fracturing are compared. First, is using a "Mechanical Service Packer (MSP) with Sand Plug" to perform both resin sand consolidation and screenless fracpack jobs. Second, is using "MSP with Sand Plug" to perform resin sand consolidation and to utilize Multizone Single Trip (MZST) tool to fracpack. Third, is using a Straddle Packer to perform resin sand consolidation and to utilize MZST tool to fracpack. The first technique was performed in wells W-1 and D-1 and the third technique was performed in well H-1

Results, Observations, Conclusions
The technique to perform resin sand consolidation as part of the primary sand control method in a new well followed by fracturing the formation to immobilize the fines is a novel technique. The utilization of a Straddle Packer to perform multizonal single trip resin sand consolidation followed by running MZST tool for fracturing has managed to reduce the operational days by more than half compared to the other techniques. Sand and fines production has been reduced significantly in wells W-1 and H-1 as a result of the novel technique.

Novel/Additive Information
The decision to perform resin sand consolidation prior to fracturing the reservoir is dependent on the Ultimate Compressive Strength (UCS) of the rock. Unconsolidated formation with UCS less than 2,000 psi is to be strengthened via resin consolidation. The single trip multizonal resin sand consolidation via straddle packer was first performed in well H-1 with 6 zones.
A Novel Engineered Drilling Solution for Improving Backreaming and Drilling Efficiency
Authors: Wong Chee Wah , Sluys Nicolas , Khirfan Mohd , Unnikrishnan Nitheesh Kumar , Al Ameri Saleh , Al Yamani Sultan Mohamed 
Published: October 2022

Abstract
The wells were drilled in the Al Nouf field which is part of The Northeast Bab (NEB) fields comprise three major structures containing some of ADNOC Onshore's largest oil reserves namely Al Nouf, Rumaitha and Shanayel, covering approximately 1,200 square kilometers and located approximately 60 km west of Abu Dhabi city. The main hydrocarbon reservoirs in these structures are Kharaib-2 (Thamama Zones ‘B’) and Kharaib-1 (Thamama Zones ‘C’). The Al Nouf field lies on a coastal/shallow marine area and presents special environmental concerns due to the proximity of delicate coastal ecologies, while the Rumaitha and Shanayel fields are located entirely onshore, in a desert region some 30 km onshore from the coastline.
The wells drilled in Al Nouf fields are cluster ERD wells with 10m spacing which are deviated from the surface. The drilling challenges include surface collision risks, unconsolidated surface formations in the surface section and total loss zones, and highly reactive shales in the intermediate section. Extensive back reaming while pulling the string out of hole may be required, with challenges often localized across problematic formations but also spreading across the entire open hole section.
Mud rheology modifications have not proved effective in mitigating back-reaming events, so a new approach has been investigated consisting of the integration of a reaming stabilizer within the bottom hole assembly (BHA). The customized reaming stabilizer is designed with passive Polycrystalline Diamond Compact (PDC) cutters mounted on the leading and trailing edges of the blades, while Tungsten Carbide Inserts (TCI) are fitted along the gauge. The tool replaced the upper-most conventional stabilizer to provide a much more efficient reaming ability while limiting any impact on the directional behavior and bending stress state of the BHA.
The paper will discuss how the substitution of conventional stabilizers within the drilling BHA with dedicated reaming stabilizers resulted in significant improvement in the wellbore condition, allowing drilling and back-reaming operations to be more efficient, and has ultimately helped drive the well construction cost down.
Safeguarding the Most Valuable Asset in Critical Sour Facilities
Authors: Maskari Mubarak , Habsy Zayid , Murugiah Jawahar Kumar , Tallentire Lesley 
Published: October 2022

Abstract
The relevance is on South of Oman operating critical sour fields with high pressure (500- 1000bar), H2S, CO2 up to 10% and 25% respectively. The field operations team, maintenance personnel, contractors, vendors conduct their activities with proper PPE adhering to safe operating procedures. However, during emergency, there is always a challenge to track, reach out and respond to people within Emergency Planning Zone (EPZ) extending to 100's of Sq.Km. This paper highlights the challenges in Emergency Response process - release of H2S gas cloud and the solution by embracing the digital technologies during these "mission critical" operations
A project had been taken on board to address the above-mentioned Emergency response challenges for real time tracking of all workforces including contractors within EPZ area and respond in a timely manner. Four key critical sour operating facilities with different complexities, infrastructure, and aging order had been considered. Company together with solution supplier had selected a cloud connected personal gas monitoring device with real time location tracking, voice over capability and multi gas sensors after thorough evaluation of sensor compatibility, Compliance to standards, Data security, Total Cost of Ownership and Deployment Staircase. Implementation had been mapped adhering the baseline stipulated in corporate Emergency Response Procedure including the mitigation controls
Different valid observations are recorded from the team travelling to sour wells / Manifolds scattered at remote locations with distance ranging from 20 km to 80 km from the central processing Facility and field operating personnel working in High pressure, sour Gas Injection compressors with discharge pressure up to 450barg. The application has been scaled to cover the red zones as well yellow zones for tracking people in Central processing Facility. Well defined feedback strategy based on Bottom-Up approach, sessions with super users, Dynamic scenarios as part of routine emergency drill with the front-line team together with key stakeholders had resulted in enhancements along the product roll out. Flexibility in accessing the application from control room, Local Emergency Control Centre through office domain
Network and the data visualization were proven to compliment the present emergency response capabilities. Ultimately, the team could react, respond, and reach out to people during H2S gas release scenario in a timely manner The team has adopted Industry 4.0 digital transformation - cloud hosted Software as a Service application with real time data available at endpoints, accessible through Role bases access control privileges. The Post Implementation Review results on sensors, application, effect on work process and culture will be part of the detailed presentation
Competitive Commercial and Technical Advantages of Digitization for On-Demand Additive Manufacturing in Oil and Gas Industry
Authors: Awadallah Mohammed , Abdelkader Mustafa , Younis Farah , Bin Zubaa Yaser , Al Zaabi Fatima , Al Ali Ali , AL Aidarous Adel , Carreiras Pedro 
Published: October 2022

Abstract
Adapting new technologies in digital transformation within ADNOC is in-line with its 2030 strategy for a smart growth, resulting in maximizing the value of every barrel. 3D printing enables ADNOC to be self-sufficient in sourcing spares locally (especially Business-Continuity). Hence, boosting UAE's economic performance through national investment and leadership.
Resilient supply chain management is the main contributor towards the success of future organizations. This enables these empower these organizations in terms of performance, profitability, efficiency, and sustainability that will directly ensures business continuity. While effective supply chain is directly dependent on logistics, inventory control, and materials handling, it is also strongly interlinked with the utilization of new technologies that will enhance the complete supply chain cycle.
This paper demonstrates a hands-on achievements in terms of introducing three-dimensional (3D) printing to ADNOC Group Companies, taking into consideration the challenges that this technology is facing to penetrate the conservative oil and gas industry and realizing its potential benefits to the business. Additionally, the importance and the achievements towards constructing Digital Library in ADNOC specifically and oil and gas companies generally was discussed along with feasibility study which was carried out to evaluate the process from the environmental and techno-commercial perspectives. The technical results exhibited advantage in matching plant's requirement in terms of performance and quality that matches or even exceeds the OEM spares. Whereas commercial advantages with around 50% savings in direct purchases and lead-times, and finally 90% reduction in carbon footprint. Furthermore, a forecasted consumption and saving within all ADNOC Group Companies was extrapolated which shows AED2.1billion worth of products will be made in UAE by 2030 once this technology adopted down the line.
Soft Computing Approach for the Prediction of Surfactant Adsorption
Authors: Kalam Shams , Abu-Khamsin Sidqi A. , Kamal Muhammad Shahzad , Patil Shirish , Al Shalabi Emad W. 
Published: October 2022

Abstract
Surfactants are commonly used in chemical enhanced oil recovery (cEOR). The quantity of surfactant loss due to adsorption on a rock directly influences a cEOR project economics. Therefore, surfactant adsorption quantification is an important area of interest. Surfactant adsorption is greatly influenced by the mineral composition present in the rock. This paper presents a novel machine learning (ML) intelligent model to predict surfactant adsorption as a function of mineral composition, maximum adsorption capacity, and surfactant concentration. Several pure minerals were used to determine the static adsorption of a novel cationic Gemini surfactant. The novel surfactant is compatible with high salinity and high-temperature environment. XRD was utilized to show the percentage of the rock-forming minerals. The solid-liquid ratio used in this study was 1 gm in 15 ml, and the time given for rock fluid interaction was 24 hours. The supernatants obtained after 24 hours of shaking and 20 minutes of centrifuging were analyzed using high-performance liquid chromatography to determine the remaining surfactant concentration. ML algorithms were applied to the dataset to predict surfactant adsorption. Hyperparameters tuning was performed using K-fold cross-validation integrated with an exhaustive grid search technique.
Surfactant adsorption isotherms were constructed from the real experimental data for each pure mineral. The dataset was divided into an 80:20 ratio for training and testing, respectively. Extreme Gradient Boosting (XGBoost) and random forest (RF) techniques were applied to the training dataset to predict the surfactant adsorption as a function of mineral composition, maximum adsorption capacity, and surfactant concentration. The remaining 20% of the dataset was used to test the models. The evaluation error metrics comprising R2 and RMSE showed good agreement of predictions with the unseen data. Also, it was found that XGBoost outperformed RF in surfactant adsorption predictions with R2 of 0.9914 and 0.8990, respectively. The developed model can be used to predict surfactant adsorption by using mineral composition and surfactant concentration. The developed model saves a significant amount of time in running the tedious and time-consuming experiments and helps to provide a good quick estimate of surfactant adsorption. This model will add a great value in the practical application of a chemical EOR project.
3D Printing Laterals for Sand Filters
Authors: Banna Rakan Wajdi , Orfali Ahmed Mohsen , Elayoubi Ensan Mahmoud , Asiri Abdulaziz Yehya , Baig Mirza Mansoor , Khan Imran A. 
Published: October 2022

Abstract
The idea is to use 3D printing technology to design and manufacture wedge wire laterals of sand filters with non-metallic material to withstand the filter operating conditions of treated seawater for oil and gas fields and reservoirs. The design of the laterals is unique and can't be achieved with conventional nonmetallic manufacturing methods due to wedge wire laterals design specifications. This modification will resolve major corrosion challenges, sand migration and meeting water quality specifications in addition to enormous cost savings compare to existing metallic materials.
Wedge wire laterals WWL of filters are designed to remove particulates from fluids to prevent contamination, media passing or damage to downstream industrial processes, equipment and oil and gas reservoirs. WWL is the main element for the filtration process and any failure or leaks will lead to media passing and affect to all downstream piping, equipment's and meeting water quality specification.
The existing materials is stainless steel 316 and it's has frequent failures, corrosion and pitting even before the T&I due date, as shown in below picture. The design of the laterals is unique and can't be achieved with traditional manufacturing methods of nonmetallic materials due to laterals technical specifications.