bluuebunny/crossref_metadata_2025_split huggingface dataset:
Specialized High Tensile Strength and Quick Disconnect Tool Used to Achieve 6,500-ft Plug Length Saves 9 Days of Rig Time
Authors: Benberber Mohammed Rebbou , De Barros Adelson Jose Calleia , De Melo Alexandre Bezerra , Iskander Mirette , Aghayarova Nargiz , Manga Patrick , Bertheux Willem Brontheis , Ledevin Pierre 
Published: November 2024

Abstract
Ensuring long-term integrity of the pilot hole through permanent plug and abandonment (P&A) presents challenges related to the maximum length of the plug, type of formation to be isolated, and the type of cement slurry used. The technology used to abandon an appraisal well with 6,463 ft of tubing in one operation is discussed. It highlights the use of specialized, high-tensile-strength, quick-disconnect tool in highly deviated and deep well conditions. The operation was successfully completed and saved the operator nine days of rig time.
The main challenge of the given appraisal well was to isolate a 6-in. pilot hole with 20,000 ft TD and 88° inclination. A specialized, high-tensile-strength, quick-disconnect tool with sacrificial 3.5-in. tubing was run in hole (RIH) and, after placement of cement across and inside the tubing, was successfully disconnected to leave 6,463 ft of the tubing in the hole. Because the job principle was close to the primary casing operation, centralizers were used with consideration to standoff calculations to determine eccentricity of the tubing with such inclination. To help ensure long-term isolation and minimize channeling, slurry with enhanced mechanical properties was used for cementation.
The primary purpose for the specialized, high-tensile strength quick-disconnect tool was to place a competent cement plug for P&A. Placement of the release mechanism near the top of cement (TOC) minimized contamination by avoiding swabbing of the cement plug while the work string was pulled out of the hole (POOH). The tailpipe remained in the cement plug to prevent cement contamination as the work string was POOH. The disconnect mechanism of the tool is simple and all risks were evaluated and considered during operational planning. Conventional abandonment methods consume significant rig time, including placement time, POOH time, WOC, and RIH to verify the plug to place the next one. Typical industry recommended plug length is usually no more than 1,000 ft, as considerable risk of stuck drillpipe and contamination were potential outcomes of this operation.
The successful application of the tool technology combined with the appropriate slurry design are discussed. Use of the proposed technology can help reduce well abandonment time and costs to operators as well as reduce the overall authorization for expenditure (AFE).
Deployment of Automated Hole Cleaning Advisor Increases Adoption of Drilling Automation Applications at a Global Scale
Authors: Arévalo P. 
Published: November 2024

Abstract
Modeling of cuttings transport has been profoundly enhanced to become the backbone of drilling automation applications dealing with well control. This paper presents the evolution and adoption of a world-leading physics-based drift flux cuttings transport model, its deployment as part of a drilling automation application validated across the globe in different environments, and the tangible benefits delivered to drilling operations.
The drift flux cuttings transport model is part of a digital twin of the wellbore and equipment deployed in real-time to continuously assess the well condition. The model has evolved over the years to become a world-leading cuttings transport model. This paper presents the continuous development of technology following agile processes to promptly create tangible deliverables for drilling operations.
The digital twin is part of a drilling automation application deploying a more holistic and automated hole cleaning advisor. The transient model is executed on demand to produce updated cuttings transport results and the associated context for it. Such results are converted into relevant information for drilling optimization engineers, hence simplifying the decision-making process. The adoption of the service is assessed globally and discussing the different regions.
The automation application containing the physics-based cuttings transport model was deployed in several locations across the globe. Some of the most sensitive deliverables of this model are the concentration of cuttings, its behavior as they are transported to surface, and the estimation of time and flow rate to transport the cuttings to surface. This kind of context information has enabled users to make informed decisions to maintain the health of the operation and avoid stuck-pipe events. Users can better decide where and for how long to circulate the wellbore after drilling a section to reduce cleaning time without endangering the formation and avoiding stuck-pipe events.
Furthermore, the hole cleaning application provides a central and concise visualization to highlight regions with high cuttings concentration and increasing risk of stuck-pipe events. The field deployments in Latin America, Asia Pacific, North Sea, Middle East, and North America Land are presented as example. Such deployments span across high-pressure, high-temperature environments, managed pressure drilling (MPD), long lateral sections, among others.
The automated hole cleaning advisor assess the wellbore condition in real-time and enhances the ability of drilling operations to react to potential drilling risks related to poor hole cleaning, thus avoiding costly corrective actions. The integration of transient modeling with drilling automation enables a safer optimization of procedures.
Optimizing Route of Produced Water Disposal
Authors: Al Siyabi Manal 
Published: November 2024

Abstract
This article presents a detailed concept selection study aimed at economically optimizing the disposal of produced water from high water cut and maturing oil reservoirs. The study is carried out on an existing oil production facility that has a built and operating network specifically for water disposal through water disposal wells (WDW). Given that forecasts indicate additional produced water will exceed the current network's capacity, this study was initiated to determine whether the existing base route of disposing of the water through disposal wells should be maintained or if alternative routes might be more economically attractive. To achieve this objective, a comprehensive analysis of key surface and subsurface factors was undertaken to assess the optimal operating conditions for disposal via water disposal wells. Additionally, hybrid and alternative disposal routes were thoroughly investigated to enhance both efficiency and cost-effectiveness in the process of water disposal.
The concept development process began with a thorough evaluation of subsurface factors that affect water disposal through wells. This involved assessing the injectivity index, which quantifies the rate of water injection in relation to pressure, and evaluating the frequency of acid stimulation required to sustain well performance. Additionally, surface factors such as water quality and disposal pressure were scrutinized to understand their impact on the efficiency of water injection rates.
The study explored two principal disposal routes: (1) complete disposal through water disposal wells and (2) a hybrid approach that integrates wells with various surface disposal methods. Surface disposal routes, including evaporation ponds and wetlands, were examined in detail to evaluate their feasibility and cost-effectiveness.
By integrating both subsurface and surface considerations, the study provides a thorough analysis of how these factors interact to influence water disposal strategies. The findings offer valuable insights into optimizing water disposal practices within the oil and gas industry, underscoring the potential for enhanced economic outcomes and improved operational efficiency. This comprehensive overview delivers a holistic approach to produced water disposal, aiming to balance both surface and subsurface technical considerations to achieve economically optimal results.
Assessment of the Environmental Risks and Policies Associated with Carbon Capture and Storage in the United Kingdom – A Case Study of the HyNet North West Project
Authors: Badejo Adeshina O. , Aminu Nuruddeen I. , Kumar Sekar Lokesh , Rita Okoroafor Esuru 
Published: November 2024

Abstract
In the United Kingdom, the North West of England and North of Wales are significantly industrialized regions generating approximately six million tonnes of CO2 industrial emissions per year. Undoubtedly, there is a need to decarbonize these regions as part of progress towards NetZero. The HyNet North West project, a £72 million project, is one of the two Track 1 projects selected by the United Kingdom government to help decarbonize these regions starting from 2025. With a focus on environmental risks, this comprehensive desk study conducts a feasibility assessment of the environmental risks and policies/regulations associated with CO2 sequestration in the United Kingdom, using the HyNet North West Project as a case study.
Using the Green Leaves III Government’s Guidelines for Environmental Risk Assessment and Management, the project’s inherent risks and hazards including groundwater contamination, surface water pollution, and potential impacts on protected species that could be affected by this development have been identified. In terms of policies, the current legal, political, and social context for this project were extensively studied. This approach aims to strike a balance between competitiveness, sustainability, and security in the execution of the project.
Based on the identified risks, an environmental risk monitoring and management plan, including pre-injection, injection, and post-injection phases, as well as risk mitigation measures, were formulated. Suggestions on how regulation and legislation can be used to achieve common energy policy objectives were provided. Recommendations were also made to outline a forward plan for the maturation of the UK’s First-Of-A-Kind Carbon Capture and Storage project, which cannot afford to fail. Overall, it was concluded that additional policies need to be implemented to support the execution of clean energy projects to meet the UK’s energy and climate goals. Additionally, the associated risks must be mitigated and contained.
Novel to this work is the identification of specific stakeholders who should be heavily involved in discussions around CCS deployment, particularly relating to this project, given its proximity to residential areas. This study identifies political and public support, especially at the local level, as essential for the project's success.
Game Changer in Chemical Reagents Design for Upstream Applications: From Long-Term Laboratory Studies to Digital Factory Based On AI
Authors: Saifullin E. R. , Gimadiev T. R. , Khakimova A. A. , Varfolomeev M. A. 
Published: November 2024

Abstract
The modern oil production industry necessitates an ever-expanding use of various chemical agents to optimize extraction processes, enhance recovery efficiency, and address operational challenges such as corrosion, scaling, and emulsion stability.Development of hard-to-recover oil reservoirs and extraction of residual oil from mature oilfields are the main reasons for the widespread application of chemical enhanced oil recovery (EOR) and improved oil recovery (IOR) techniques. Each oilfield and reservoir have unique conditions and fluid properties. To successfully implement chemical EOR (Enhanced Oil Recovery) and IOR (Improved Oil Recovery) technologies, it is essential to select or develop specific chemicals or chemical formulations tailored to the particular conditions of the reservoir. However, development of such reagents takes a lot of time and resources, it is limited by available initial reagents and precursors in the market. This work presents a new approach for developing chemicals using chemoinformatics models and artificial intelligence. The proposed approach consisted of three stages: generation of synthetically available molecules using the "Virtual Factory" algorithm, prediction of properties using a graph neural network with selection of the best candidates, and laboratory synthesis and validation of the predicted properties. The Virtual Factory algorithm used 159 of the most widely produced precursors on the local market and 10 templates of most common in practice reaction. The result of the algorithm was 5731 digital structures of surfactants of five various chemotypes. Graph neural network was designed to predict to predict interfacial tension (IFT) which is the most crucial property for surfactant flooding technology. A training set consists of 55,477 data points of molecule structural properties along with 218 IFT measurements for different reservoir conditions and oil properties for the training set. From 5731 generated digital surfactants structures, 4 surfactants with the lowest IFT among various chemotypes for oilfield X conditions were selected based on graph neural network predictions. The surfactants were synthesized in the laboratory and IFT was measured for oilfield X conditions to validate the neural network prediction.
Carbon Dioxide Conversion To Advanced Carbon Nanotubes
Authors: Wattana P. , Thivasasith A. , Nunthakitgoson W. , Rodaum C. , Wattanakit C. 
Published: November 2024

Abstract
The conversion of CO2 into valuable substances is a topic of great interest for decarbonization. Among them, the CO2 conversion to advanced materials such as carbon nanotubes (CNTs) has emerged as promising CO2 utilization. In this work, we have successfully developed catalysts and process to convert CO2 to CNTs. We developed catalysts by loading active transition metals on to hierarchical zeolite for CNT synthesis using CO2 as raw material. The synthesis of CNTs from CO2 over the developed catalysts was carried out via a chemical vapor deposition (CVD) process. The quantity and quality of the resulting carbon nanotubes were determined using thermogravimetric analysis (TGA), scanning electron microscope (SEM), transmission electron microscopy (TEM), and Raman spectroscopy. The synthesized CNTs were also evaluated for their current response using cyclic voltammetry (V vs. Ag/AgCl) method. By optimizing metal type, metal loading, zeolite topologies and pore structures (hierarchically porous or conventionally microporous), we successfully converted CO2 to CNTs over the metal-loaded hierarchical zeolite catalysts. The CNTs produced using the 25wt.% Fe on hierarchical FAU zeolite provided the most promising result with a high CNTs yield of 15.4%, an average CNTs diameter size of 23.1 nm, and ID/IG ratio of 0.56 indicating high quality CNTs. The synthesized CNTs were tested and exhibited higher current response compared to commercial CNTs. This enhanced performance highlights the significant contribution of the small diameter and superior quality of our synthesized pure CNT. Transition metals play a crucial role as catalysts in the decomposition of CO2 during the CNTs synthesis. Moreover, well-distribution of metal nanoparticles on the hierarchical zeolite contributes to enhanced catalytic activity, consequently resulting in more favorable CNTs synthesis outcomes. This work demonstrates conversion of CO2 towards highly conductive CNTs-based materials, which have many potential applications including energy storages, sensors, electronic circuits, etc.
Overcoming Realtime LWD Limitations of Longest Horizontal Drilling: A Unique Experience from Abu Dhabi
Authors: Abbas Nashat. , Noukhatha J. Al , Radwan K. , Aljaberi S. , Alqaydi N. , Arenas Milena. , Shrivastava Chandramani 
Published: November 2024

Abstract
Drilling long horizontal sections has been modus operation for some offshore operations by ADNOC for efficient exploitation through extended reach wells. Getting Realtime data for operational decisions becomes hugely challenging as the footage drilled goes higher, due to limitations posed by mud pulse telemetry and associated noise. This study presents a unique experience where logging-while-drilling (LWD) data could be streamed with high quality in Realtime in a record length extended-reach drilling (ERD) well through complex carbonate reservoirs with deployment of an advanced new solution.
Record drilling footage of more than fifty-two thousand feet was achieved in a long horizontal well drilled through a complex carbonate formation offshore Abu Dhabi. Operations suffered with the loss in real-time communication and degradation of real-time data quality after forty-one thousand feet of drilling. A novel technology of advanced telemetry was deployed to drill next section of planned additional eleven thousand feet that provides increased bandwidth for high fidelity Realtime data transmission with better data quality even at higher rates of drilling (ROP) in extreme conditions for measurements while drilling (MWD) and logging while drilling (LWD) in record measured total depth.
This new mud pulse telemetry platform enabled transmission of high quality Realtime MWD and LWD data to surface while drilling the deepest and longest section of the well towards the total depth at fast penetration rates. Good quality density images could be sent up hole with more than 100-ft/ hr. drilling rates in addition to the petrophysical triple combo data from the depths of &gt;52,000 ft (about 15.85 km). Advanced data algorithms and embedded intelligent modulation methods pushed the boundaries towards achieving this unique experience.
This paper illustrates good geosteering practices in a challenging long horizontal well with carefully selected LWD program to achieve the target and reduce risks. The success of high quality Realtime data from such ERD wells opens new opportunities for drilling such wells through complex settings while still being able to acquire high-quality data without worrying about legacy limitations of mud pulse telemetry.
CO2 Transport Specification, Purification and Dehydration Solutions
Authors: Cao H. , Greene M. , Kuppler J. , Ali M. 
Published: November 2024

CCUS is one of the key solutions to reduce emissions like carbon dioxide (CO2) in the atmosphere and minimize the effect on global warming. CO2 is separated from other gases at large industrial facilities like refineries, natural gas power plants, steel mills, and cement plants, or from the atmosphere. The two most common technologies for CO2 capture are membranes using physical separation and amines using chemical absorption. The bulk CO2 that is separated must go through additional purification steps to be ready for transportation. Once the CO2 meets pipeline specification, the CO2 is further compressed using high pressure to change the CO2 from a gas to a supercritical liquid. Pipelines are the most common mode of transport. After being transported to the well-characterized and permitted geological storage site, the CO2 is injected underground into deep rock formations where it is safely and permanently stored. Geologic formations have safely contained a variety of liquids and pressured gases such as oil, natural gas and naturally occurring CO2.
It is expected that several CCUS projects are coming live, and it is also expected that they are connected through a CO2 transportation network. Such a network will be a combination of ship, trailer, train, and pipelines. Carbon steel is a natural choice as construction material for the CO2 transportation system since it has excellent strength, is relatively cheap and is readily available in large quantities. Carbon steel corrodes when exposed to CO2 and water and/or glycol, therefore it is crucial that the transportation systems are operated in a manner that prevents formation of aqueous phases (Müller et al., 2023). Although treatment specifications vary by project, some specifications are commonly accepted. First, water in the treated CO2 typically needs to be less than 50 ppmv. The water content of &lt;50 ppmv is well below that suggested to avoid the risk of corrosion for transport in pipelines and is set to avoid the risk of formation of ice in the liquefaction process equipment, rather than for any issues with transport containers. Second, for liquefaction, water specification in the treated gas can be as high as 50 ppmv. This is due to the higher liquefaction temperature of CO2 compared to other gases, like natural gas or nitrogen. Finally, glycol needs to be completely removed. This last point often disqualifies triethylene glycol (TEG) units for CO2 dehydration service.
A Case Study on Enhanced Top of Cement Predictive Modelling Validated Against Bond Logs
Authors: Sierra Natalia Leon , Fechner Fara 
Published: November 2024

Abstract
To comply with requirements of local regulations, challenges can arise when cement operations do not go as planned and cement does not circulate to surface. A coal seam gas (CSG) operator in East Australia requested validation of the top of cement (TOC) in three wells (Wells A, B, and C). This was attributed to losses during cementing with uncertainty related to wellbore geometry or a combination of the two. Having the correct TOC estimated with pressure map correlation could help ensure an effective barrier was in place.
Post-job data was gathered and collated as inputs for each well for software simulation. Data included wellbore parameters from drilling data, fluid properties, volumes and rates of fluids pumped, and returns measured in trip tanks and on job pump data acquired for pressure mapping. Iterations were simulated based on the cases until accurate pressure mapping was observed. For Well A, pressure matching calculations between the design and execution phases had iterations in calliper hole size, expected loss zones, and loss rate/volume based on what was observed on the surface. For wells B and C, no losses were encountered. No open hole calliper data was available; hence, the uncertainty with regard to the open hole size and washouts were the key variables to iterate.
Software analysis predictions with post-job field data provided the operator with surface pressure comparisons and predicted TOC for these wells. The accuracy of the simulations were within ± 50 m, later confirmed by cement bond logs (CBLs) conducted post-job. Data screening for the inputs, results analysis, iterative requirements, and comparison of simulation results with log data recorded are discussed. For well A, deviation between the prediction and the actual log result was 3 m.For well B, deviation between the prediction and the actual log result was 20 m.For well C, deviation between the prediction and the actual log result was 58 m.
Log validation of software simulation predictions of the TOC provide operators confidence in the accuracy of predictions. This potentially reduces the need for CBL logs and can result in cost savings for operators in addition to increased trust in available cement tools.