bluuebunny/crossref_metadata_2025_split huggingface dataset:
Understanding High-Frequency Torsional Oscillations HFTO in Rotary Steerable Applications: Observations, Learnings, and Tales of Caution
Authors: Wilson J. K. , Robles E. 
Published: November 2024

Abstract
High-Frequency Torsional Oscillations (HFTO) continue to be a challenge for Rotary Steerable System (RSS) Performance. While ruggedization of downhole tools has improved significantly over the years and has enabled tools to survive these violent events, excessive vibrations can still lead to drilling inefficiencies, shortened lifespans of components (increased replacement rates during tool servicing), or occasionally errors in sensor readings. This study shares some key observations during HFTO events including relationships between other vibration modes, behavior with other commercially available vibration mitigation tools, mitigation strategies, and practical limitations.
Case histories are presented highlighting HFTO behavior and what this vibration mode looks like within drilling data. Real-time, log, and high-frequency data are all examined to illustrate the differences and variability of each. Mitigation strategies are addressed in detail, looking at parameter adjustments, changes to the Bottom-Hole Assembly (BHA), and different types of dedicated vibration mitigation tools. Benefits and shortcomings are shown for each.
Results show the benefit of planning for this type of vibration event and illustrate how the specific drilling application can impact the dynamic response of the BHA. Some unique dynamic characteristics have been observed and are discussed. One such behavior that has been noted is the presence of a torsional beating phenomenon when utilizing a torsional spring-like type of vibration mitigation tool. The physics of this behavior is further examined through detailed modeling and simulation, accurately replicating the observed field measurements. General HFTO observations over the years have also led to the development and implementation of a new at-bit viscous damper type of HFTO mitigation device. Due to the success of this at-bit mitigation device, it has been integrated directly into the Rotary-Steerable System (RSS), removing the need for additional tools or connections in the BHA, and is now a standard technology on all RSS deployments.
The data presented in this study is the first documented case of a torsional beating phenomenon during an HFTO event. In addition to this, general HFTO observations are shown in a concise format to share the knowledge gained thus far with this type of vibration. The success resulting from the implementation of the only at-bit HFTO mitigation device is also highlighted.
Non-Metallic Low Carbon Footprint Solutions – Qualification of Structural Materials and Case Study of Modular & Adjustable Pipeline Crossing Supports
Authors: Brattekås Jon Inge , Berg Mathias V. 
Published: November 2024

Abstract
CSUB has developed a modular and adjustable Pipeline Crossing/Freespan Support designed to support pipelines subjected to freespan due to uneven seabeds or scouring. This support can also be used for crossing supports of rigid pipelines. CSUB has qualified the use of Glass Fiber Reinforced Polyester (GRP) material in accordance with DNV standards, leveraging over three decades of extensive use. The main findings indicate that high-quality GRP is environmentally benign, exhibits very low degradation in seawater, and is well-suited for offshore applications. These conclusions are corroborated by independent third-party evaluations from organizations such as DNV. The Adjustable Pipeline Crossing/Freespan Support is patent pending.
CSUB wish to acknowledge Mr. Qasim Saleem at Offshore Pipeline Department of Aramco for valuable insight and contribution during the development and testing of the Adjustable Pipeline Crossing/Freespan Support.
The Adjustable Freespan Support was tested at CSUB's factory in Arendal in 2023. The tests involved pulling the foundation under the pipe on a concrete floor, installing wedges, and securing them using a threaded mechanism. The objective was to demonstrate the functionality of the support and measure the operational loads.
Tests were conducted using 8" (1250 kg) and 28" (4840 kg) pipes with two sets of wedges, 15 degrees and 30 degrees. The recorded loads for maneuvering the freespan support equipment are as follows: Table 1Recorded loads for maneuvering of freespan support equipmentTaskMaximum forceCorresponding friction factorPulling foundation under pipeline1160 kg0.62Moving wedge into position, manually55 kg0.34Table 2Measured torque/load taken from 28" pipeline with weight of 4840 kg and maximum lifting height of pipeWedgeTorque appliedResulting lifting forceMax. lifting height15° Wedge100 Nm4840 kg220mm30° Wedge100 Nm2220 kg645mm150 Nm3640 kg200 Nm4840 kg
The tests proved that the Pipeline Freespan Support operates as intended for:
Movement of assembly under pipeline Wedge operation, including connection to the threaded rod and lift mechanism, effectively transferring the pipeline load to the support.
Research and Experiment on Electrification Technology for Deep Heavy Oil Reservoir
Authors: Yang L. L. , Yuan A. W. , Long H. , Zhang F. X. , Wu X. M. , Yang X. , Yang X. Z. , Liu F. S , Li C. X. 
Published: November 2024

Abstract
Focus on the problems such as high energy consumption, high carbon emission and low steam dryness in deep heavy oil, research and field test on electrification technology and supporting technology series had been carried out. And three types of electrification technology series had been developed. According to the characteristics of different oil Wells, the corresponding technology of downhole high power electric heating assisted steam injection to increase dryness had been formed. Through numerical simulation analysis, the principle of increasing dryness by electric heating assisted steam injection and the application limits of reservoir were defined. The regulation method of electric heating power was established in combination with the construction of ground wind power and solar power. Field tests showed that the electrification technology series could effectively meet the oilfield production needs and provide technical support for green and low-carbon development of deep heavy oil.
Integrating Solar Farm for Sustainable Oilfield Operations
Authors: Tagong K. 
Published: November 2024

Abstract

Objective
PTT Exploration and Production Public Company Limited (PTTEP) is currently the operator of S1 oilfield located in Kampheangphet province, Thailand. Previously, the electricity used in operating the S1 oilfield was primarily generated by in-plant Gas Turbine Generators (GTG) fueled by natural gas. Recognizing the importance of sustainable energy development, PTTEP initiated "Lan Sang Arun project", a 9.98 MW solar farm designed to provide green energy to support the operations of the S1 oilfield and reduce carbon emission.

Method and Procedure
The project involves building a 9.98 MW solar farm and the related infrastructure to supply green energy to support S1 oilfield operations. Integrating the solar farm into the S1power management system presents unique challenges. Unlike most conventional solar farms that connect to either the grid or the user, Lan Sang Arun plant is a special case because it connects to both the in-plant gas turbine generators and the public grid. The power management system required modifications to enable smooth power control between the solar farm, the GTGs, and the grid.

Results, Observations, Conclusions
The solar power plant was successfully constructed and started operation in July 2023. The renewable energy generated from an Sang Arun solar plant are now used to support the operation of S1 oilfield, reducing the natural gas consumption by approximately 0.5 million cubic feet per day, which lead to carbon reduction of 13,000 tCO2e per year.

Novel/Additive Information
Lan Sang Arun solar farm is the first project in Thailand to supply electricity from a renewable source to support petroleum operations. It contributes to both PTTEP's and Thailand's net zero greenhouse gas emission targets and serves as a showcase for oilfield electrification in Thailand.
Successful Application of Integrated Fiber-Optics with Coiled Tubing Operations Enhances Acid Stimulation Treatment
Authors: Ahmed Usman , Noguera Jose , Alfonzo Ruben Ortega , Chishti Sadaf 
Published: November 2024

Abstract
Matrix-stimulation methods are often applied in Carbonate reservoirs to ensure uniform distribution of treating fluids / acid and successful stimulation in the hydrocarbon-producing wellbore. The treating fluids typically take the path of least resistance (or high permeability zones), thereby requiring the use of diverters for effective stimulation of low permeability and/or damaged zones. However, under downhole conditions, it is challenging to directly determine, measure, or simulate the effect of a specific acid / diverter operation. As a possible solution, distributed temperature sensing methods can be used to understand the complex downhole dynamics, effects of treating fluids on the formation (through transient temperature response) and most importantly, qualify and quantify the success of a stimulation operation.
Of interest to this study is a horizontal, open-hole producer well in the prolific Carbonate formation in one of the major fields. As part of the objectives to effectively optimize acid and diverter placement, an integrated fiber-optics enabled coiled tubing intervention operation was planned for this study. The technology involved deploying a 2.375-in. coiled tubing string with a 0.125-in. tube wire housing a triple fiber-optic cable. Distributed temperature sensing (DTS) measurements were taken at several stages of pre-and-post stimulation that involved visualization and interpretation of temperature traces to identify fluid distribution and optimize acid-diverter strategy.
In a systematic process, DTS surveys at depth for two scenarios: well base-line conditions followed by pre-stimulation solvent treatment were first conducted. The DTS analysis included heat maps and transient temperature curves along the entire wellbore. Comparisons between the baseline and pre-stimulation flush conditions provided qualitative insight into areas of the well that took a greater proportion of the pre-treatment fluid. This information was then used to revisit the original acid-treatment plan and update the stimulation plan to optimize the acid-diverter placement in target zones. As part of the optimized strategy, 45% of the open hole was treated with a proprietary acid-diverter system and the remaining 55% with 20% HCl acid.
This unique approach of fiber-optics enabled coiled tubing operation and analysis resulted in an optimized acid program reducing the total acid volume by over 30%, thereby saving the operator around 20% from the allocated budget on this well. In summary, the data presented here demonstrates that the distributed nature of fiber-optics monitoring in conjunction with intelligent coiled tubing and pumping strategies can be effectively used to improve and optimize future acid-stimulation jobs.
Introduction of Stimulation with Single-Phase Retarded Acid Help to Achieve Superior Results in Highly Depleted Reservoir Newly Drilled Wells Offshore Republic of Congo
Authors: Mutschler V. , Gallut J. , Lamiable A. , Bremner S. , Artola P. , Reyes J. S. , Boussaidi L. , Tardy P. M. J. 
Published: November 2024

AbstractRedevelopment of the Tchibeli main field in offshore Republic of Congo began with the drilling of five new wells targeting the Upper Albian formation. Being carbonate in nature, these reservoirs benefit from initial hydrochloric (HCl) acid stimulation to enable and promote economic production. A project was devised with a stimulation vessel pumping single-phase retarded acid and a particulate/fiber-based diverter.The wells were drilled and completed with a 9 ⅝-in. cemented casing. This casing was perforated using 7-in. tubing-conveyed perforation (TCP) guns with a shot density of one to six shots per meter. A single well was completed using a ball-actuated fracture port completion with the target of completing three acid fracturing stages in a single well. For this well, acid fracturing modeling software was used to predict fracture coverage and ideal placement of fracturing ports. Optimization of stimulation fluids was carried out using core flow testing with formation cores. Analysis of the cores showed a variation in permeability to gas (10 md to 2,000 md) and carbonate content across the pay zone. By investigating different fluids and injection rates, engineers were able to optimize treatment design and react during operations without compromising on quality. Degradation tests of the particulate diverter were conducted and evaluated to ensure the correct product used.Well stimulation operations were carried out using a stimulated vessel to enable efficient use of time and achieve large stimulation design volumes in one bullheading pumping operation. During the process, three stages were completed in a single load out for the acid fracturing candidate at rates up to 40 bbl/min. This was followed by the completion of three matrix wells in a single load out, with the final well being completed at a later date. All these stimulations were performed offline with the rig performing the flexible drilling and completion sequence. Post-stimulation production results were analyzed and matched with the stimulation software production model to further improve the accuracy of the simulation.This campaign used a combination of single-phase retarded acid for matrix and acid fracturing operations, plus degradable particulates and fiber diverters to achieve complete zonal coverage of matrix treatment. Core testing showed pore volume to breakthrough (PVBT) results in high-permeability cores above 345 md. Plus, cores were used with high calcite content instead of the traditional dolomite/limestone lithology that is often presented in PVBT results. The combination of core data and production prediction was able to further develop stimulation fluid placement in modeling software.
Improved Method of Estimating Cable Pull-In Resistance by Factoring Variable Seabed Friction as a Function of Cable Displacement
Authors: Onesto S. , Cheryian K. , Aldo M. , Ashton G. , Brunning P. 
Published: November 2024

Abstract
The aim of this technical paper is to present an enhanced methodology for improving the estimation of subsea cable resistance (pulling loads) during cable pull-in. The methodology has been proposed based on a validated case study demonstrating the cable second end pull-in by considering the seabed friction in terms of the changes in cable displacement. The product under installation in this case study was a power cable being pulled into a J-tube. Accurate estimation of friction coefficients are essential for the reliable estimation of pull- in loads. Hence, a detailed geotechnical study has been performed and presented.
During the pull-in, the power cable must overcome the seabed friction, which includes lateral and axial components, both of which depend on the soil embedment and resistance. Unlike the conventional industry approach, in this methodology, the pull-in tension and loads are estimated by factoring the impact of breakout friction and residual friction explicitly (discrete friction values for every cable displacement value). Variable soil friction coefficients based on cable displacement have been defined during the study. Improved reliability in predicting the pull-in load is of benefit for accurately designing the product under installation, the pull-in head, selection of the platform winch, winch wire and other accessories. The design parameters for the pull-in analysis include maximum allowable pull-in load of the cable, seabed topography and cable surface roughness.
The results of the case study which are operationally significant are the maximum pull-in load at the platform winch and maximum load on the cable pull-in head. In general, the pull-in loads at platform winch and cable pull-in head are observed to be maximum and equivalent when the cable pull-in head reaches the platform topside. However, for specific cases when the breakout friction is significant due to the cable embedment in the seabed soil, the peak pull-in loads are observed at the commencement of pull-in. This peak load developed on the cable pull-in head is amplified at the platform winch due to the capstan effect arising from the J-tube curvature and friction between the cable and J-tube. It is evident from this case study that the definition of breakout friction and residual friction as a function of cable displacement is relevant, when the effects of soil embedment (breakout friction) dominate the resistance.
Enhancing Engineering Document Analysis Through Structured Data Mapping
Authors: Rascanu G. , Dzhusupova R. , Guo Z. 
Published: November 2024

Abstract
This paper presents an innovative approach for mapping engineering documents, particularly unstructured PDF files, to knowledge graphs, offering significant benefits for both engineering processes (i.e. such as ‘review-check-approve’ process) and AI-powered development.
The method aims at improving efficiency, enhancing decision-making capabilities, reducing document turn-around duration, and thus decreasing costs while increasing productivity.
Specific advantages include: Quick overview for reviewers to prioritize tasks - more weight can be given to identified main topics with less time on the side topics.Improved quality: interrupted relationships and isolated entities may indicate inconsistency that is usually overlooked in the traditional review process.A faster review process achieved through common understanding between reviewers, resulting in a subjective time reduction (average 10% improvement) while enhancing quality.
Our method leverages advanced natural language processing (NLP) techniques, sentence transformers and large language models (LLMs) to transform complex document content into structured knowledge visual representations. This approach addresses the challenge of efficiently extracting information from unstructured engineering documents by first identifying relevant keywords, that align with the main topics of the document, through a robust initial process. The extracted keywords define the framework upon which the entire knowledge graph is built, ensuring its relevance and utility.
Central to our methodology are novel techniques in LLM-based prompt engineering that enhance entity and relationship extraction in complex engineering contexts. These techniques incorporate chain-of-thought reasoning for improved accuracy. Furthermore, we introduce a robust process of relevant keyword extraction as an initial step, which sets the foundation for all subsequent stages from entity extraction to final graph presentation.
The resulting knowledge graphs serve as a method of enhanced visual understanding of documents that are often complex and difficult to comprehend through human analysis alone. By extracting patterns and connections that would otherwise be challenging to identify or understand, these graphs facilitate simplified document comprehension and improved data integration.
Our proof-of-concept results demonstrate the effectiveness of this method in supporting decision-making processes in the energy sector. Using this methodology as the ground base we outline directions for future AI development applications such as generating contextually relevant responses of the interrogated documents, summary creation and integration with other AI technologies.
Large Scale Electric Heater
Authors: Ahmed-Seddik Bouhadjar , Kolhe Pushkar , Kumar Navlok 
Published: November 2024

Abstract
Decarbonizing industrial heat is paramount for achieving climate targets and facilitating a successful energy transition. High-temperature industrial processes, often exceeding 500°C, present significant decarbonization challenges due to their heavy reliance on fossil fuel combustion. This is particularly critical for energy-intensive sectors such as oil and gas, iron and steel, cement and minerals, chemicals, and pulp and paper.
Electrification emerges as a promising solution for these industries; however, current technologies capable of achieving the requisite high temperatures and scalability are limited. This paper introduces a groundbreaking technology: the electric heater utilizing inductive technology. This system generates heat through induced current in the secondary coil, which is subsequently transferred to the gas or fluid used in the process.
Powered by low-carbon electricity, the electric heater is poised to become the preferred choice for numerous energy-intensive applications. This innovative inductive heater technology offers a sustainable and scalable solution for process heat. Successful proof-of-concept testing at a 0.5 MW scale has demonstrated the inductive operating principle and its performance.
Leveraging materials and design practices proven in generators and power transformers, the inductive heater is projected to achieve temperatures exceeding 1000°C at a power scale of 1000 MW. This technology provides a viable decarbonization pathway for various industrial processes and offers potential operational value through end-user co-creation. The inductive heater not only addresses the high-temperature requirements but also aligns with the global push towards sustainable energy solutions, making it a critical component in the future of industrial heat management.
Alternative Remediation Technique for Safely and Reliably Performing Single-Trip Perforation and Squeeze Operations
Authors: Arabie Blake , Koppenhaver Carey 
Published: November 2024

Abstract
Complex wells lead to complex abandonment strategies, which lead to creative solutions for early-life to end-of-life well operations. When balancing unknown well conditions with personnel safety, operator standards, and government requirements, effective solutions that satisfy all are difficult to develop. Multiple well entries are often required, exposing the operator to costly, time-consuming, and high-risk operations. Successful well intervention is critical for well integrity, maximizing oil and gas production, and ensuring operational safety.
In the case of a Hess-operated deepwater well in the Gulf of Mexico, drilled in 2006 and temporarily abandoned in 2007, the complexity of well entry was high due to the development of multiple flaws in the wellbore. A risk assessment of a traditional multi-trip system resulted in high-risk well integrity issues, subjecting the team to potentially severe safety breaches, leaving the team to devise an innovative alternative. Through collaboration between Oilfield Services Professionals (OSP) and Hess Corporation, a single-trip system solution reduced risk and provided a safe plan forward.
This paper introduces the alternative single-trip remediation technique designed for safely and reliably performing perforation and squeeze operations. The proposed method integrates hydro-mechanical perforation technologies with an improved squeezing mechanism, enabling the execution of both processes in a single trip. This integration reduces operational time and minimizes the Health, Safety, & Environmental (HSE) impact and risks associated with standard practices.
Through a series of pre-job qualifications and field studies, this technique successfully demonstrated significant improvements in operational efficiency and safety. The application of the developed solution provides a comprehensive evaluation of the single-trip system's performance, including comparisons with traditional methods and discussion on its versatility for various wellbore designs. The results indicate a notable reduction in non-productive time (NPT) and enhanced control over the perforation placement and quality of cement squeezes. Adopting this single-trip approach enhanced well-remediation operations, offering substantial cost savings and improved safety outcomes for the oil and gas industry.