bluuebunny/crossref_metadata_2025_split huggingface dataset:
Digital Implementation and Data Analytic for OCTG Running as Tool to Control Non-Expected Operational Cost and Enhance Efficiency in Drilling Operations for Operator Company in Abu Dhabi
Authors: Amorocho A. , Elkasrawi A. , Abdelazim A. , AlRashdi A. , Shamlam A. Bin , Nuaimi M. Al , Nunez Y. , Blanpied C. , Cavanha T. , Blues S. 
Published: May 2023

Abstract
Responding to requirements of Operator Company in Abu Dhabi to automate and strengthen processes of running casing and tubing, a patented digital solution has been implemented, which timestamps all key phases of the tubulars’ lifecycle from rig receipt to running then to rig return, while enabling continuous improvement through post-running data analytics.
The solution relies on unique individual pipe traceability, through a combination of different methods of marking such as – data matrix, RFID & barcodes. These markings are read using a variety of digital tools including – smartphones, tablets & cameras.
The solution has already been deployed in North & South America, Europe, and Asia, totaling over 100 successful jobs worldwide. Operator Company in Abu Dhabi was the first operator in the Middle East to try the solution in 2022.
The below section summarizes the solution results based on the feedback from the first three wells piloted by Abu Dhabi Oil Company. The value chain is broken down into three key categories as follows:
– Pre-running: the solution brought an increased level of quality control paired with an automatically generated pre-tally list. Further to this, an increase in personnel is safety assisted by a reduction in tubular handling and removal of personnel from high-risk positions. – During running: the accuracy of the running sequence was ensured by the utilization of the solution ‘‘Watchdog Alerts’. These highlighted to the user any deviation from the original plan, preventing error and minimizing any downtime generated. All of this was made available in real-time in a cloud environment to anyone within the Operator Company with credentials for accessing the system. – Post-running: monitor and compare rig performances through digitally enabled data analytics
In conclusion, significant cost reduction (from 15 to 45 k$ per job for a 70k$ rig day rate), mitigating risks of non-productive time by reducing human errors (from 5 to 15 hours per job), ensuring safety and integrity of the well and enabling operators to track its assets and monitor running operations in real-time.
Sustainable Chemicals Development for Drilling Fluid Application
Authors: Ramasamy J. , Al-Arfaj M. K. 
Published: May 2023

Abstract
In oil and gas drilling industry, drilling fluid plays a vital role and is being circulated through out the drilling operation from spudding to completion. Drilling fluid provides hydrostatic stability to wellbore. It is also used to cool down the downhole tools. In addition to the above mentioned functions, drilling fluid is responsible to carry cuttings to surface, provide lubricity and stabilize shale formation. There are variety of chemicals added to drilling fluid to provide properties viscosity, density, emulsion stability, lubricity and fluid loss control. Developing environmentally friendly additives. Development of drilling fluid chemicals that are sustainable and benign to environment to provide the aforementioned properties is a significant step towards achieving sustainability and reducing carbon footprint besides suitability for drilling across aquifers and offshore environments. We have studied the applicability of used cooking oil to obtain fatty acid and their derivatives and evaluated its performance as emulsifiers and lubricants for drilling fluid applications.
A Holistic Approach to Achieve Zonal Isolation Improvements Across 8 1 2 Inch Hole On the in an Offshore Field
Authors: Hassan Azza El , Abdelatif Mohamed Samir , Hamidzada Ahmedagha , Andrews Kerron , Toki Takahiro 
Published: May 2023

Abstract
In an Offshore field, off the coast of Abu Dhabi, well integrity objectives are becoming more difficult to achieve as open hole sections become deeper, laterally longer and more highly deviated. In this mature field, one of the main challenges of well construction is successfully cementing long production-casing strings covering multiple reservoirs across the 8½-in sections. This paper describes some of the techniques and best practices that were applied on these wells to achieve the required zonal isolation.
Achieving zonal isolation across multiple reservoirs through a single or multi-lateral configuration is a major challenge in this field. The reservoir formation is porous and requires a special gas tight design or impermeable cement system. Inadequate hole cleaning due to poor standoff attributed to complex well design is another main limitation, resulting in insufficient mud removal leading to an uneven cement distribution around the casing. Additionally multiple pressure-testing cycles are required post cement-setting and during the completion phase, a practice that can destabilize the cement system causing it to fail. Moreover, controlling loss circulation while running or after landing casing is another challenge in this field.
To overcome these challenges a series of customized improvements were applied subsequently through continuous improvement and implementing lessons learnt from previous operations. The elements of this approach included introducing higher density cement systems to cover the horizontal sections, while retaining the ECD within the required margins. Another element utilized was that of two cement slurries; Lead and tail, which were designed to achieve controlled ECD. An additional element which was also implemented addressed enhancing the flexible expandable gas tight slurry by adding Latex to achieve a fit for purpose solution. The last element of this strategy included improving hole cleaning and mud removal efficiency by optimizing spacer design and volumes in addition to the loss circulation additives in the spacer systems.
Throughout the operation, the cement jobs were executed successfully with no losses. Cement jobs were evaluated through running job design simulation Vs execution parameters comparison. The approach resulted in substantial improvement on log responses. Additionally, after implementing the approach, logs were compared to offset wells from the same field to track the improvement done.
The paper reviews enhanced practices implemented to overcome challenges faced during well cementing. Being able to find a solution to this complex problem, delivering a comprehensive cement quality, and improving cementing integrity on these wells resulted in expanding this approach to the rest of the fields. The improvement measures that were developed are now being adopted across all jobs to yield a similar outcome.
Three-Dimensional Positional Uncertainty Based on Along-Hole Depth, Inclination and Azimuth Accuracies
Authors: Bolt Harald , Harbidge Philip 
Published: May 2023

Abstract
Along-hole Depth (AHD) is the most fundamental subsurface wellbore measurement made. Well depth is the main descriptor of wellbore position, measured from zero depth point (ZDP). This is translated into vertical depth (V) using inclination (I). V is the main descriptor subsurface wellbore events and then North (N) and East (E) act as the Qualifying descriptions of V.
Well depth is commonly described as measured depth (MD) and is used to describe well construction, navigation and collision avoidance, drilled geologies, reservoir properties, fluid gradients and interfaces, production, and subsurface positioning of well services. AHD is a calibrated and corrected well depth measurement defined using a specific rig-state and can deliver improved subsurface position and positional uncertainty.
Well depth, I and azimuth (A) are used to calculate subsurface 3D position. Well depth is measured at surface, represented by drillpipe or wireline length. I and A are subsurface measurements referenced to the provided well depth. These together provide the navigation information required to arrive at the 3D positions of N, E, and V. These positions are used to define the location of subsurface events such as well placement, geological horizons and fluid contacts.
This paper outlines a method ("3D method") for defining 3D subsurface positional locations using "way-points" (Bolt 2021). Way-points represent a sequential series of specific, calibrated, 3D positional locations each defined by calibrated and corrected AHD. Based on Pythagorean geometry using AHD, I, and A measurements, these are converted into N, E, and V positions. Each way-point has a specific N, E, and V positional uncertainty.
Four component accuracies are used to describe the individual AHD, I and A measurement uncertainties at each way-point: calibration and observation, applied correction, model-fit, and a fixed-term applicable to all observations. AHD, I, and A measurement uncertainties which are converted into individual interval N, E, and V positional uncertainties and sequentially concatenated.
The method provides a simplified yet accurate solution to 3D positional and positional uncertainty. The calculations demonstrate the dependency of the positional and positional uncertainty results on both interval spacing between way-points and measurement accuracy. The example results demonstrate that each well has its own specific and unique N, E and V positional uncertainty description. Specific positional uncertainty requirements of operators can be answered to through instrumentation accuracies and way-point interval spacing defined in the well survey program. Well placement can be more easily portrayed, reservoir characteristics more confidently reported, and asset volume estimation improved.
Multiphase Fluid Erosion Modeling for Rapid Development of Shunt Tube Isolation Valve for Openhole Gravel Pack
Authors: Omer Farhan , Rudic Aleksandar , Song Lijun , Gupta Susheel Kumar , Kamath Raghuram 
Published: May 2023

Summary
This paper presents the effective use of computational fluid dynamics (CFD)-based erosion modeling to optimize the development of gravel-pack completion equipment, in this case a shunt tube isolation valve (STIV), which enables total zonal isolation following gravel-packing operations. A novel erosion- and debris-resistant approach to the design of the STIV was developed. The product development methodology incorporated the use of an iterative CFD erosion model to quantify the erosion rates on a proposed novel STIV flow conduit for gravel packing. The erosion model simulated a typical gravel-pack treatment using a multiphase fluid model of carrier fluid (8.5-ppg density) with 100,000 lbm of 30/50 proppant at 5 ppa pumped at 10 bbl/min. Multiple iterations of the flow conduit were designed and analyzed to minimize the pressure drop, the flow velocity, the erosion rate, and recirculation. This design methodology enabled a successful qualification using a full-scale erosion test, followed by successful closing and pressure tests. Expensive retesting was eliminated; post-test correlations demonstrated that the CFD model accurately predicted areas of high erosion, and the quantity of material loss was within practical limits. The development approach and modeling method provide a reliable tool for the development of new gravel-pack completion equipment and comparable products, saving time and avoiding expensive delays, failure investigations, and retesting costs.
Effect of Hydrogen on Mechanical Properties of Completion Pipeline API Steels
Authors: Perozo N. , Amirhosseini S. Fazel , Tavakoli M. , Holzmann J. , Neubert V. , Jaeger P. 
Published: May 2023

Abstract
The main objective of the presented work is to evaluate the effect of hydrogen service conditions on the mechanical properties of API steel grades used for well completions. The evaluation methodology implies a preconditioning of the steel specimens to long-term exposures under high-pressure hydrogen atmospheres and compare the results of subsequent mechanical tests with those of steels not being exposed to this gas. The aim of this research is to compare the performance of different API grades when subjected to hydrogen service. The outcomings of the study will help to evaluate long-term integrity of completion systems and materials compatibility for hydrogen storage applications. Mechanical tests like notched-tensile tests, hardness determination and impact tests were performed, in order to detect the embrittlement of the metals by comparing results between specimens not previously charged with hydrogen and specimens being subjected to a hydrogen atmosphere under high-pressure. The notch tensile specimens were pre-stressed to 80% of the nominal yield strength, in order to force and assure the hydrogen diffusion into the notch area where localized increased tensile stresses are concentrated. Furthermore, by means of carrier gas hot extraction analysis the hydrogen content in the samples was measured, to give an indication of the absorption capacity of these grades under the stated conditions. The API grades L80, P110 and Q125 have been selected to represent a wide and popular selection of ductility and yield strength. All samples were subjected to a series of mechanical tests to determine the presence of hydrogen embrittlement. The results show different behavior of the materials after being exposed to a hydrogen atmosphere, from the noticeable decrease to even a "no effect" on the mechanical properties. The results of notch tensile tests of the steels L80 and Q125 are showing some level of hydrogen embrittlement, compared to P110, being the one least affected by the presence of this gas. The measurement of hydrogen content in the samples delivers similar results for all the grades. Microscopic analysis shows the structure of the crystal lattice of the steels studied, helping to understand, together with the state of stress, how sensitive the material is to be affected by hydrogen embrittlement. There is no literature that describes the hydrogen effect on the mechanical properties of API steels used for tubings and casings in well completions, nor their sensitivity to hydrogen embrittlement. The results of this research are of great importance to give an idea of the compatibility of the steels that can be used for high-pressure hydrogen operations, such as hydrogen underground storage as well as to evaluate the potential recompletion or use of existing wells.
Curing Hydrodynamic Instability During Balanced Plug Cementing
Authors: Harestad K. , Karimfazli I. , Ghazal A. , Harestad M. , Saasen A. 
Published: May 2023

Abstract
It is shown how the flow from pumping cement through an open-ended pipe very quickly turns direction and the cement flows upwards. This rapid change in flow direction indicates that a diverter tool, which leads the cement slurry perpendicular out of a closed ended pipe does not have any function. The placement of a balanced plug is feasible. However, a high-density fluid above a lighter fluid is not stable. The phenomenon is known as Rayleigh-Taylor instability. In principle, to be reasonably stable, the interface must be horizontal. The longer the interface is, the more unstable is this case. Thus, it is difficult, or sometimes impossible, to create a stable situation in a deviated well section; especially if the well section diameter is large. Observations show that it is possible to modify density differences, thickening time and viscosity differences such that the success rate can be between 40 and 60%. Using a floatable cement foundation tool, this success rate will increase to more than 95% as shown by North Sea success values. The use of such a tool is described and its performance is justified by numerical analysis of cement flow.
Curing Hydrodynamic Instability During Balanced Plug Cementing
Authors: Harestad K. , Karimfazli I. , Ghazal A. , Harestad M. , Saasen A. 
Published: May 2023

Summary
It is shown how the flow from pumping cement through an open-ended pipe very quickly changes direction and the cement flows upward. This rapid change in flow direction indicates that a diverter tool, which leads the cement slurry perpendicularly out of a closed-ended pipe, does not have any function. The placement of a balanced plug is feasible. However, a high-density fluid above a lighter fluid is not stable. The phenomenon is known as Rayleigh-Taylor instability. In principle, to be reasonably stable, the interface must be horizontal. The longer the interface is, the more unstable is this case. Thus, it is difficult, or sometimes impossible, to create a stable situation in a deviated well section, especially if the well section diameter is large. Observations show that it is possible to modify density differences, thickening time, and viscosity differences such that the success rate can be between 40% and 60%. Using a floatable cement foundation tool, this success rate increased to more than 95% in North Sea applications. The use of such a tool is described, and its performance is justified by a numerical analysis of cement flow.
A New Method of Kick Evaluation Based on Energy Analysis
Authors: Ye Yuguang , Fan Honghai , Liu Yuhan , Tao Zhenyu , Diao Haoyu , Zhou Fei 
Published: May 2023

Abstract
With the gradual progress of drilling to the deep layer, the formation conditions become more and more complex. The safe density window of drilling fluid is narrow, and well kick and overflow occur frequently. Aiming at this problem, this paper proposes an overflow evaluation index - overflow formation energy. From the perspective of energy analysis, overflow is regarded as the process of formation fluid doing work on the wellbore, and the power of overflow work can reflect the strength of overflow, so this power is defined as the overflow formation energy. Based on the model established in this paper, the effects of different types of overflow fluid, invasion rate of overflow fluid, drilling fluid density and formation pressure coefficient on overflow formation energy are analyzed. The overflow formation energy of gas is the highest. As the invasion rate of overflow fluid increases, the energy of overflow formation gradually increases. The data of 7 overflow wells are analyzed, and the corresponding overflow formation energy is calculated. It is found that the throttling circulating well killing method is more appropriate when the overflow formation energy is small. The overflow formation energy can quickly evaluate the overflow situation, provide theoretical basis for well control operation, and reduce the probability of well control operation risk.
Rising to the Challenge of Drilling Through Depleted Reservoirs
Authors: Pedersen Roar , Zapata Bermudez Fernando 
Published: May 2023

Abstract
To overcome the challenges of drilling depleted reservoirs, a new technology was needed as part of a cost-effective solution. An innovation campaign was facilitated by a major oil company R&T (research and technology) department in the North Sea to identify concepts enabling high depletion in drilling through reservoirs. Several concepts were evaluated, and a packer in the drillstring was defined as a necessity by the major oil company. Drilling through depleted reservoirs has become more and more common in operations run by both oil operators and drilling companies, in fields that have matured. Drilling these wells introduces an increased risk for crossflow and losses and a series of mitigating actions have been put in place to obtain an acceptable risk level.
This paper will focus on describing the steps taken to develop a packer that provides a seal between the drillpipe and the production casing, being part of the drilling BHA and spaced out to stay inside the casing. It's large bore through allows high flow rates and deployment of intervention tools through it. By setting the packer, it becomes a qualified V3-barrier, validated as per ISO14310 and/or API11D1, enabling the operator to cement and sidetrack efficiently, saving additional trips and rig time. This successful technology cooperation will help oil operators and drilling companies to expand its capabilities for drilling depleted and complex reservoirs and further increase the overall recovery factor for its mature fields.
Rising to the challenge, means to improve the confidence in drilling with limited drilling window and avoid uncontrolled risks by using a Drillstring Annulus Sealing Packer that when set, provides a seal between the drillpipe and the casing, the packer activation is meant to be the last option in a series of mitigating measures as the wellbore will be abandoned if activated.
Pipe Feeder Robot for Land Drilling Rigs
Authors: Mikalsen Kenneth , Raunholt Lars , Tawfik George 
Published: May 2023

Abstract
The objective of this paper is to present a new and innovative fully automated tubular handling robot that can feed drill pipe and casing from pipe storage on ground to the well center of a land drilling rig in a fast, accurate and all-in-one operation.
In recent years, experience has been gained with large electric robots for pipe handling both offshore and onshore. As reliability is confirmed, the robotic operations on rigs are expanded. The most recent development is a Pipe Feeder Robot for handling of pipe and subs all the way from pipe storage on the ground to the well center of the land rig, including spinning into the stick-up. The technology is based on qualified heavy-duty electric robots for pipe handling, but the new machine is configured in a way so that it can be transported from rig to rig without large interfacing work.
The industry has great expectations with the introduction of robotics for red zone management and eliminating manual operations and human exposure to heavy machinery. Expected value would be a substantial saving in rig days due to fast, precise and consistent operations and removal of people out of harm's way. In addition to improved safety, reduced OPEX, less downtime and faster installation, the Pipe Feeder Robot lowers the noise and the carbon footprint due to higher energy efficiency and less GHG emissions. Also, the precise motion control of the robot enables digitalization of the drilling process.
The paper will present performance data and results from test operations. The Pipe Feeder Robot picks up pipe (or casing), rotates from horizontal to vertical, and spins into the stick up in one operation, whereby hazardous handovers are avoided and a hands-free handling operation is created, replacing the work of four conventional operations. Reliability of robots in hostile environment will be analyzed with regards to field experience of similar technology from land rig drilling operations. Finally, the value to the users will be substantiated.
The paper will provide test results and experience from the tests of a heavy-duty all-electric Pipe Feeder Robot. It will provide valuable input for decisions for the future use of industrialized robots in the oil and gas upstream industry.