bluuebunny/crossref_metadata_2025_split huggingface dataset:
Autonomous Directional Drilling Simulator Development for the Drillbotics 2021-2022 Virtual Competition
Authors: Fernandez Berrocal Miguel , Shashel Alina , Usama Muhammad , Hossain Md Akber , Baris Gocmen Emre , Tahir Ali , Sui Dan , Florence Fred 
Published: March 2023

Abstract
The work focuses on the drilling control algorithms as well as Artificial Intelligence (AI) technique implementation into an in-house real-time drilling simulator developed by the Drillbotics® Virtual Rig Team from the University of Stavanger, the winner of 2021-2022 Drillbotics Competition.
The designed simulator consists of a topside model capable of calculating block position, surface hookload, surface torque, and bottom hole pressure. To achieve drilling efficiency, a formation-based rate of penetration (ROP) optimization module is running in real-time, where the safe-operational windows are considered to reduce/avoid drilling accidents, like stick-slip, axial vibrations, poor hole cleaning, and low efficiency etc. The obtained optimal WOB and RPM by solving such ROP optimization are used as setpoints and then fed into the rotary steerable system module (RSS module) to steer the bit following a planned path. Such path is designed with multiple Bezier curves that can pass given target coordinates and maintain low dogleg severity (DLS). Furthermore, the high-tech AI methodologies are integrated to the simulator to smartly manage downhole pressure via perceiving and interpreting the data, learning through the trial, training through given policy, and taking optimal actions offered by the AI-agent.
The simulator is demonstrated to be a powerful and user-friendly tool for path design and optimization, real-time path control, and drilling performance optimization. It provides interactive and automatic operations of steering a bit passing multiple given target points and optimizing drilling behaviors to achieve high efficiency and low costs. From the results, the simulated (real-time) trajectory steered by the automatic RSS module integrating with surface drilling/control modules has small deviations from the planned trajectory. In the meanwhile, the simulator can precisely detect formation changes, accurately control the downhole pressure, and automatically optimize the drilling speed.
The progress of the whole simulation can be followed through the web-based graphical user interface (GUI) remotely, where the depth-base data view, time-base data view and 3D graphical wellbore trajectories are visualized. After drilling, data analytics is conducted so that useful information from operational drilling data can be extracted and subsequently evaluated for post well-analysis.
A Water-Base Drilling Fluid for Controlling Deep-Reservoir Extreme Conditions in an Abu Dhabi Gas Shale Play
Authors: Manescu Gabe , Veer Balazs 
Published: March 2023

Abstract
Drilling for hydrocarbons in the extreme reservoir pressure and temperature remains one of the most challenging operation, especially related to drilling fluids. A combination of excellent teamwork and fluids technology proved to be the recipe for successfully drilling in these extreme conditions for TotalEnergies shale-gas play, onshore Abu-Dhabi, United Arab Emirates.
The success on drilling deep (6,200mMD), long lateral displacement (2,000m) wells with an integrated global operator is a balance, dependent on frequent and transparent communication between the team members, of excellence in well planning, extensive laboratory testing, procurement and supply of resources, flawless field execution, and a diligent post-well review with the operator. More commendable is this success was achieved while dealing with operational challenges amplified by the pandemic restrictions on personnel and materials movement.
The design of the environmentally and economically acceptable aqueous fluid met stringent fluid design criteria, wellbore and temperature stability for drilling and data acquisition performance goals. The high-density HT drilling fluid is designed to have the minimum amount of solids by using a Sodium Chloride combined with a Sodium Bromide brine, weighted up with ultra-fine grind barite. Viscosity and fluid-loss are controlled with a unique additive, a dual-function, branched synthetic polymer.
The environmentally acceptable aqueous drilling fluid delivered a barite sag-free operation in these highly deviated wellbores, delivering a balance between a low-equivalent circulating density and excellent hole cleaning, compatibility with the reservoir formation, and long-term stability to enable logging with no formation closure in a deep, high temperature drilling environment. Additional achievements of the fluid were the low HPHT filtration, good lubricity for increased rate of penetration, and reusability on the subsequent wells thus improving the sustainability profile by reducing disposal. Successful coring and extended wire logging the reservoir section was an excellent test for this fluid.
The balance between a brine base, filtrate-loss, and viscosity-increase additive for fluid design, coupled with excellent field engineering provides the long-term thermal stability of a drilling fluid able to tackle drilling a reservoir reaching a depth past 6 kilometers.
Extended Reality and Gamification for Drilling
Authors: Chatar Crispin , Lokesh Rajat , Kamboj Vineet , Saetern Danny 
Published: March 2023

Abstract
The video game industry grew from about 10 billion in 2007 to more than 135 billion in 2018. Many industries including the oil and gas industry have been monitoring new and emerging technologies in this space as the capability evolves. The result of years of research, investigation into latest technologies, and proving the use cases for our industry have been a fit-for-purpose design. Key collaboration enabled the utilization of gamification for training, increased data visualization, improved operations, and the ability to create virtual twin of worksites. These improved capabilities increase safety and efficiency. This paper aims to share lessons learned and key points to consider when utilizing gamification and extended reality (XR) to deliver these solutions. This will be done by discussing several technologies investigated and their application to real cases. Specifically, products in use today as well as many proof-of-concept projects already in production will be highlighted.
Gamification is not about creating video games. Gamification is about adding gaming elements to nongaming environments. Gamification can engage consumers, employees, and partners to inspire, collaborate, share, and interact. Gamification has the potential to address specific industry concerns. The industry can translate technologies previously thought only to be of value to the gaming industry into valuable energy industry applications. Like many other industries now utilizing gaming technology to adapt their own solutions, it is time for the energy sector to realize the potential applications of gamification. The potential upside to gamification is billions of dollars saved, and immeasurable increases in safety and operational efficiency. One example of this will center around training.
This can be achieved with a game engine to create the learning environment and target a specific set of goals. All the tools to create a gamified system can be achieved with the right technology, but strong collaborations with technology leaders in other fields are necessary. Today, with the support of game engine partners, we can push the exercise to any platform be it mobile, desktop computer or virtual reality (VR). The gamification process can greatly enrich two-dimensional and three-dimensional experiences. We can easily use a tablet for three-dimensional learning experiences. A personal computer can be used for the most in-depth training process. Virtual reality can be an option to add muscle memory to the learning process as well. Collaboration is another example of an important function we will showcase. We will show the solution built as a multiuser experience that can bring experts from many domains together in one workspace on their platform of choice. In this example, we will show how these functions can be integrated with already existing software.
Modeling of Axial Rotary Drilling Dynamics as a Step Towards Drilling Automation
Authors: Whitlow Zackary , Mahjoub Mohamed , Auld Sonny 
Published: March 2023

Abstract
Analysis of low frequency axial drilling dynamics from block velocity input to surface weight on bit (SWOB) or differential pressure outputs, shows significant regional variation. This range in dynamics poses a robustness challenge for automated drilling control systems. Many factors influence drilling dynamics such as pipe stiffness, mud properties, tortuosity, friction, bit design, and BHA geometry. A simple analytic model representing axial drilling dynamics is described and compared to a finite element drilling model and to drilling data. The analytic model shows that axial drilling dynamics may be represented by a first-order transfer function with a time constant dependent on axial stiffness and drillabillity.
A Short Summary of Retrofit Multilateral Technology Implementation
Authors: Berge Frode , Fathi Marcus , Rød Anne Mette , Fjelde Tomas 
Published: March 2023

Abstract
On the Norwegian Continental Shelf there are many fields and wells in late life production. There are also many nearby drilling targets with limited volumes to add. This situation requires new mindset in order to optimize tie-ins of new reserves to existing infrastructure. Retrofit multilateral well solutions are regarded as one enabeler in this context since they enable tie-in to existing producers from nearby targets through deep sidetrack operations.
There are many pre-requisites that must be in place for such solutions to be suitable. In addition, the risk of partial success involves loss of an existing producer.
A few such wells have been constructed by the operator in the last couple of years. The requirements and challenges are discussed. The implementations show that it is technically feasible to use conventional multilateral technology in ways that enable installation in producing wells. Improvements to existing solutions are sought in order to facilitate future implementations and to improve robustness of this technology.
Detailed Dynamics Modeling Helps to Assess the Effect of Stabilizer Design on Drill String Vibrations
Authors: Nguyen Khac-Long , Mahjoub Mohamed , Dao Ngoc-Ha , Menand Stéphane 
Published: March 2023

Abstract
Various stabilizer types are used in the industry, such as bladed stabilizers with straight or spiral blades, roller-reamers, and other emergent forms. Their designs are proved, via many in-field measurements, to have a significant impact on vibration levels. Although experimental data is extremely valuable to rank the available design options, testing the different stabilizers can be costly and sometimes risky. In addition, in-field conditions can be difficult to control making the comparisons between stabilizers even more complicated. Assessing the design impact using numerical simulations represents an interesting alternative to provide objective comparisons based on tests in a controlled environment.
When a stabilizer is rotating, the contact forces between its different blades and the wellbore are transient. A static approach like torque and drag or directional models is then insufficient to properly investigate the stabilizer's design characteristics. Therefore, a time-domain dynamics approach is adopted in this work. A detailed modeling of bladed stabilizers including the blade geometry (number of blades, spirality, and blade width) and friction characteristics are introduced in an existing time-domain model. These characteristics are used to compute the contact forces between the wellbore and each individual blade.
This numerical model is applied to quantify the effect of stabilizer design in terms of vibration, from straight blades to highly spiraled blades. First, a parametric study of blade design and wellbore inclination effects on stabilizer vibrations is presented by considering different stabilizers in straight well conditions. Simulations of an actual drill string configuration in an unconventional well is discussed. For vertical, curved, and horizontal sections, the acceleration levels, contact forces, and rotation speeds are investigated. These analyses can constitute guidelines about stabilizer design to minimize vibrations.
The novelty of this work is to introduce the geometry details of the stabilizers in the time-domain dynamics to differentiate designs in terms of likelihood to trigger vibrations.
A Full Laboratory Study on the Physical and Mechanical Properties of a Bismuth Plug
Authors: Hmadeh Lewaa , Elahifar Behzad , Sangesland Sigbjørn , Abrahamsen Andreas Elmer 
Published: March 2023

Abstract
Well plugging and abandonment can be very expensive, time consuming and problematic. This is because it is the least considered process during a well's life cycle. Setting a plug downhole in an efficient and successful manner is governed by several factors, one of which is the type of sealant used. Portland cement, a commonly used sealing material, turned out to be an inadequate barrier material due to its porous and permeable properties, as well as its insufficient long-term sealing integrity.
Bismuth, an alternative sealing material, demonstrated several distinctive characteristics, such as being non-porous, expanding after cooling, and corrosion resistant. In this study, samples of bismuth-tin metal alloys were deployed and allowed to solidify in carbon steel pipes. For comparison, cement plug samples were also prepared under the same conditions; the only prevailing difference was the plug length where that of cement was longer than that of bismuth. Both bismuth and cement samples were subjected to extensive physical, hydraulic, and mechanical push-out tests after curing. Leakage tests using nitrogen gas were also carried out on cement and bismuth samples.
As a safe, economical, and environmentally friendly alternative to cement, bismuth appears to be a promising material. Preliminary results clearly manifest the weakness of cement, where high leakage flow rates and early plug breakdowns were witnessed during the tests carried on it. It was observed that short plugs of bismuth were able to withstand a higher differential pressure compared to longer cement plugs. Another interesting finding was that the bismuth plug kept on building up its strength with time even after solidifying. However, the trend of this "strength-build-up" eventually became minimal with time. Hence, the optimal curing time of the bismuth plug was concluded to be somewhere around 24 hours, unlike that of a cement plug which must be left a minimum of 5 days to cure.
The aim behind the conducted laboratory experiments is to understand the sealing ability of bismuth to a steel pipe and compare its sealing performance to that of cement. This paper represents the first part of an extensive research which at later stages will be tackling the sealing performance of a bismuth plug in the annulus and its interaction with the surrounding formation.
Sealing Ability of Barrier Materials for P&A Application: Investigation of Casing-Barrier Interface
Authors: Moreira Paulo , Khalifeh Mahmoud , Govil Amit 
Published: March 2023

Abstract
The bonding properties between a sealant and steel casing are an important component of well barrier. However, there is no consent about how sealing materials should be tested and qualified, and the understandings around the bonding interface and its mechanisms of failure remains uncertain. A custom setup and a systematic interface analysis procedure was established to test the hydraulic bond sealing properties of different sealants, and to investigate their interface with a L80-Cr13 steel casing. The results of hydraulic bond sealability was correlated with macro and microstructural evidence of the bonding interface to understand the behavior and the performance of class G cement and a geopolymer recipes. The geopolymer recipe showed improved sealing performance in relation to class G cement. The interface analysis suggests that, in addition to the mechanical interlocking mechanism, the geopolymer sealant has a strong bond with the coating of the steel casing, as a secondary adhesion mechanism. Understanding the interface and the mechanisms of failure may be the key to further develop current and future sealants, and to reduce risk of leak and to reduce cost with well intervention in P&A operations.
Applied Well Testing Analysis Considerations in Channel Reservoir Coupled with Dynamic Simulation Model
Authors: Mesdour Rabah , Aboubakar Coulibaly , Almalki Faisal 
Published: March 2023

Abstract
In this paper will describe the integrated workflow between two well-known reservoir engineering approaches PTA and 3D dynamic simulation. This workflow provides significant help to understanding the channel sand reservoir properties, predict possible well interference and provide consistent well's production prediction forecast. The available geological background, seismic data to map the combined channels, and even well by well Petrophysical correlation showed limited capabilities to characterize the channel heterogeneity due to the reservoir continuity change consistently, and for most of the cases the channels features are unpredicted. Giving these limitations, it is necessary to consider using other engineering approach; e.g. Pressure Transient Analysis (PTA), Rate Transient Analysis (RTA), Dynamic Simulation models to narrow down the uncertainties for better understanding of the reservoir quality.
This customized workflow was completed and used in this study to cover all uncertainty parameters during the calibration and prediction of the wells’ performance. It consists to calibrate the geological model using Pressure transient Analysis (PTA) and dynamic simulation model output to enhance the geological model calibration assessment under uncertainty. As results; multiple geological realizations were obtained to cover the possible uncertainty ranges for each parameter. Furthermore, the Well prediction scenarios were performed to evaluate the range of wells’ production prediction forecast under multiple geological realization uncertainty to be more confident in predicting the wells performance under different well constrains and come up with minimum and maximum values. The main challenge associated with the development of channel tight gas sand reservoirs is how to predict the channel attributes and location; e.g. channel width, height, and how to quantify their effect on the well's long-term performance. This workflow will help to quantify the channel properties, interference between wells, and it will guide you on how to select the new well locations for better business planning.
Chelating Chemicals: A Solution to End the Battle with Calcium Sulfate Scale
Authors: Alotaibi Fares , Almubarak Tariq , Alhamad Luai , Al Moajil Abdullah 
Published: March 2023

Abstract
Calcium sulfate inorganic scale deposition is a major challenge that can block tubulars and hinder flow assurance during hydrocarbon production and water injection operations. This scale can form when high sulfate water gets in contact with water containing high content of calcium ions. Dissolving calcium sulfate is problematic due to its low solubility in water and common inorganic acids. Many scale dissolvers exist in the industry; however, the dissolving performance varies significantly when applied to calcium sulfate field samples. The main objective of this study is to evaluate the efficacy of three commercial calcium sulfate dissolvers for possible applications in the field.
Field scale samples were characterized using X-ray diffraction and scanning electron microscopy with energy dispersive spectroscopy (XRD/SEM-EDS) to determine its composition. The HPHT aging cell was used to conduct the experiments at a temperature ranging from 77 to 300°F to evaluate the performance of several calcium sulfate dissolvers. The testing involved static dissolution tests to identify the optimal dissolver, scale dissolver to inorganic scale ratio, temperature influence, surface area influence, and the appropriate soaking time. Compatibility and thermal stability tests were also explored to avoid formation damage issues during the removal treatment. Additionally, corrosion tests were performed using low carbon steel metal coupons to assess the dissolver corrosivity at 200 and 300°F.
The scale dissolvers compatibility and thermal stability were presented up to 300°F. The performance of the dissolvers generally increased as the temperature and soaking time increased. The scale dissolver chemistries were tested at high pH conditions and most of the tests exhibited a low corrosion rate of &lt; 0.05 lb/ft2 with no significant pitting at 200°F or 300°F for the duration of the soaking time. One of the tested scale dissolvers failed the corrosion test at 300°F and two dissolvers thermally degraded when exposed to high temperature.
This work is derived from testing actual inorganic scale field samples and shares the difficulty of dissolving such scale samples. The work also systematically compares three commercial scale dissolvers to resolve this issue.
Dynamic Characteristics of Supercritical CO2 Injection in Depleted Carbonate Oil Reservoir for its Sequestration Potential: An Experimental Study
Authors: Zhou Xianmin , Yu Wei , Wu Yu-shu , Al-Abdrabalnabi Ridha , Khan Sarmad Zafar , Kamal Muhammad Shahzad , Elsayed Mahmoud 
Published: March 2023

Abstract
To reduce the amount of CO2 in the atmosphere and mitigate the severe consequences of climate change, capturing, utilizing, and storing CO2 has become very important for human survival. For utilization of CO2 in reservoir engineering practice, CO2-enhanced oil recovery (CO2EOR) as a mature technology has been widely applied in several types of reservoirs such as sandstone, carbonate, and shale gas/oil reservoirs, and the focus of concern is to study oil recovery efficiency and its influencing factors over the past few decades. Recently, more and more researchers are paying great attention to the geological storage of carbon dioxide in depleted oil reservoirs where scCO2 is injected as a displacing agent for secondary and tertiary oil recovery. Unfortunately, there is a lack of laboratory research on scCO2 sequestration in such reservoirs in terms of capacity, two-phase flow (the mixture of scCO2 and residual oil and water), injectivity of scCO2, and permeability loss of rocks. In this study, we evaluate the dynamic characteristics mentioned above subjective is based on laboratory results.
Several experiments, including different injection modes such as horizontal and vertical injections, and their effects on displacing residual oil and water by scCO2 after water flooding has been performed using reservoir carbonate rock, live crude oil, and seawater under reservoir conditions.
As a result of this study, the experimental methodology to obtain the scCO2 storage capacity of the depleted oil reservoir was proposed for the first time, and the calculation of scCO2 storage capacity assumes that the scCO2 dissolves into residual water and oil after scCO2 injection. This study found that the main scCO2 storage mechanism is pore space storage (structural trapping) for depleted oil reservoirs. Based on experimental results, the storage efficiency is found to be closely related to the permeability of rocks. In addition, the scCO2 injectivity and permeability loss of the rock were evaluated for a depleted carbonate reservoir, which was displaced by scCO2 injection at the final stage of the oil recovery process. The experimental results show that the scCO2 injectivity is not strongly affected, although the relative permeability to scCO2 slightly decreased after the scCO2EOR process. The experimental results can be applied directly for the evaluation and strategy of scCO2 storage and can be used to simulate the performance of the injection process of scCO2 storage.