bluuebunny/crossref_metadata_2025_split huggingface dataset:
All Metal Wellbore Intervention Tools as an Alternative to Motors
Authors: Pearson Allan , Luchak Mark , Curle Robert 
Published: March 2023

Abstract
Step-changes made by the development of a hydraulic casing reamer shoe built to land casing in problematic wellbores has now led to the development of a serviceable all-metal wellbore intervention tool. By employing a similar all-metal drive system as the casing deployment HSRT: Hi-Speed Reaming Tool into thru-tubing sizes, these compact, retrievable and serviceable tools are being deployed effectively in harsh environments. Cost-effectiveness and ease of service make the TT-HSRT: Thru Tubing Hi-Speed Reaming Tool an ideal alternative to downhole motors in certain intervention applications. TT-HSRT's can be deployed in harsh high temperature environments (250°C / 482°F) and are compatible with acids, solvents and nitrogen required in various wellbore stimulations. Those conditions are quite detrimental and costly to a standard elastomer power section in a positive displacement motor. Another advantage the TT-HSRT has over a motor is a much shorter bottom-hole assembly (BHA) length and ease of serviceability.
Current industry offerings do not provide the RPM range, the custom wash head configurations, or compatibility with third party milling-style heads. The original casing-deployment high speed reaming tools were designed with drillable all metal internals to aid in effective casing landing; in the thru-tubing version the proprietary internal drive system was scaled down to create a serviceable and retrievable tool to be used in jetting, descaling, stimulations, and other various casing and thru tubing interventions. The thru-tubing HSRT design uses industry-standard pin or box down connections, allowing the option to use third party wash heads and milling style heads which can be quickly changed in the field.
This technology provides workover engineers with a low-cost optimization option for wellbore interventions, with the ability to complete multiple operations in a single run. This translates to valuable time savings as well as cost savings on repair and maintenance. Another major benefit is the internal drive system which has proven to be very reliable.
Three thru-tubing sizes are available and are all under one meter in length. The tools contain zero elastomer or o-ring seals. The high RPM and low torque drive system give the tool a strong cost-saving advantage over traditional ‘elastomer and coated rotor’ style power sections found in downhole motors, particularly where a high torque requirement is not needed to complete the work.
This paper will outline the development of this technology versus a positive displacement downhole motor and include international and domestic case histories outlining the tools’ use.
Down Hole Data Driven Optimization on Bit, Parameters and BHA Lead to an Outstanding Performance in Deep Gas Drilling
Authors: Kouzaiha Rami , Cleboski Christopher , Vrnak Kyle , Daechsel Dustin , Al Rawahi Nadir 
Published: March 2023

Abstract
Deep gas drilling the early Devonian unconformity in Oman is an extremely challenging hard and abrasive application fraught with a diverse set of PDC drill bit challenges and objectives, particularly in the 8 3/8″ vertical section where between 2 to 4 fixed cutter drill bits can be necessary to reach total depth. Each trip can significantly impact well construction cost and delay production on stream dates. Using high frequency digital data collected at the drill bit and detailed forensic analysis of drill bit photographs a new, physics based, drilling equipment and parameter strategy was developed.
The section requires drilling approximately 2,000m of hard and abrasive interbedded Sandstone and Shale formations to around 5,000m vertical depth. Drilling performance is typically limited by severe wear to the PDC cutting structure or motor failure from significant torsional and lateral vibrations. High frequency digital data was captured at the bit in conjunction with output data from an automated photometric dull grading system over several wells to identify dysfunction type. The results were then analyzed by vendor and operator SMEs collaboratively to optimize drilling parameter performance and provide insights into optimal cutter shape and grade selection to further reduce drilling dysfunction.
Using downhole high frequency digital readings to understand down hole vibrations and the impact of formation interaction on bit dull has led to changes in the cutting structure and the applied drilling strategy. Different drilling approaches were applied to each formation layer to manage interbedded transitions as well as to increase depth of cut for improved drill bit dynamic stability. Insights were derived from an automated dull grading system assisted in optimizing cutter shape and grade selection in the select parts of the drill bit cutting structure. The photometric analysis also helped refine drilling parameters for a more efficient drilling by increasing axial loading on hard formations that then resulted in increased ROP. Additionally, newly developed high abrasion resistant cutters placed optimally in the drill bit at the highest work locations based on automated dull grading feedback resulted in extended cutter life helping to keep the bit sharp and maintain the high rate of penetration through the various layers reaching final section depth with consistently high rate of penetration.
The execution of the new physics-based drilling strategy has resulted in improved bit dull grade conditions which helped reaching the section final depth in one run with reduced downhole dysfunctions. that resulted in a section drilled without trips and with reduced well construction costs. The section is 32% faster than the offsets and was drilled 7 days earlier compared to plan.
Comparison of Zirconia Nanoparticles with Conventionally Used Silica Nanoparticles for HTHP Drilling Applications
Authors: Ahmad Hafiz Mudaser , Iqbal Tanveer , Yaseen Saima , AlNabbat Yousif Yagoob , Murtaza Mobeen , Mahmoud Mohamed , Patil Shirish , Kamal Muhammad Shahzad 
Published: March 2023

Abstract
Well-designed formulations of drilling fluids are required for drilling operations to improve rheological and filtration properties. The rheological properties and fluid loss during the drilling process are severely affected at the deep well with high temperature and pressure conditions. This study investigates the comparison of zirconia nanoparticles and conventionally used silica nanoparticles on rheological and filtration properties at temperatures ranging from 76°F to 122°F. Sodium-bentonite dispersion in deionized water was used as the base drilling fluid.
Rheological properties were determined at different temperatures using a Discovery Hybrid rheometer with various concentrations of nanoparticles from 0.2 wt.% to 0.75 wt.% concentrations. Steady shear rheology experiments were performed to study drilling formulations’ shear stress, viscosity, and yield stress. Temperature ramp rheology tests at 76°F and 122°F were performed to analyze the effect of increasing temperature on viscosity. The filtration tests were conducted to study the fluid loss properties of drilling fluids at various concentrations of nanoparticles. Linear swelling analysis of clay in the presence of drilling muds was performed to study the shale inhibition properties of prepared drilling formulations.
The incorporation of nanoparticles significantly enhanced the rheological properties such as yield stress and viscosity at various concentrations and temperatures. Rheological properties of zirconia muds compared with silica muds for various concentrations of nanoparticles. Temperature ramp rheology tests showed that zirconia muds have enhanced viscosity at 0.75 wt.% compared to the counterpart of silica mud. A decrease in fluid loss was observed for zirconia muds compared to the base mud while fluid loss increases with increasing concentration of silica nanoparticles. The incorporation of nanoparticles in the drilling fluids significantly reduced the swelling of clay compared to the swelling of clay in deionized water.
This research supports the extensive interpretation of water-based drilling fluids using zirconia nanoparticles and a comparison of drilling properties with silica-based fluids for high-temperature applications. The potential use of zirconia nanoparticles in drilling fluid formulations provides the way forward for the improvement of fluid loss characteristics, shale inhibition, and rheological properties.
Viscometer Readings Prediction of Flat Rheology Drilling Fluids Using Adaptive Neuro-Fuzzy Inference System
Authors: Abdelaal Ahmed , Elkatatny Salaheldin , Ibrahim Ahmed 
Published: March 2023

Abstract
Flat rheology drilling fluids are synthetic-based fluids designed to provide better drilling performance with flat rheological properties for deep water and/or cold environments. The detailed mud properties are mainly measured in laboratories and are often measured twice a day in the field. This prevents real-time mud performance optimization and negatively affects the decisions. If the real-time estimation of mud properties, which affects decision-making in time, is absent, the ROP may slow down, and serious drilling problems and severe economic losses may take place. Consequently, it is important to evaluate the mud properties while drilling to capture the dynamics of mudflow. Unlike other mud properties, mud density (MD) and Marsh funnel viscosity (MFV) are frequently measured every 15–20 minutes in the field. The objective of this study is to predict the viscometer readings at 300 and 600 RPM (R600 and R300) of the flat rheology mud in real-time using machine learning (ML) and then calculate the other rheological properties using the existing equations. The developed model using adaptive neuro-fuzzy inference system (ANFIS) predicted the viscometer readings with an acceptable accuracy. The maximum average absolute percentage error (AAPE) was less than 7 % and the correlation coefficient (R) was more than 0.96 for training, testing and validation.
The Industry's First Real-Time Pseudo Gamma Measurements From an Instrumented Steerable Motor Using High-Frequency Drilling Dynamics Sensors
Authors: Sugiura Junichi , Jones Steve 
Published: March 2023

Abstract
Downhole drilling motors are the workhorse of our industry and are used on almost every land well drilled globally. This makes an instrumented drilling motor the perfect tool for geosteering with near-bit inclination, drilling-dynamics and formation-identification sensors. Already proven drilling motor technology has been upgraded with miniature embedded sensors to provide real-time continuous inclination, advanced drilling dynamics, and pseudo-formation-identification data. The sensors are sized to mount into existing drilling motor components without adding length or compromising the mechanical integrity.
The high-frequency drilling-dynamics measurements, including lateral vibrations, axial vibrations, stick-slip, high-frequency torsional oscillation (HFTO) and motor back-drive dynamics are measured in the motor. The sensor unit applies advanced signal processing routines to the high-frequency vibration measurements downhole and converts the vibration data into pseudo gamma (pGamma) measurements, which have been correlated with measurement-while-drilling (MWD) gamma measurements in lateral wellbores. pGamma can alert the driller as soon as the bit starts cutting new formations, as compared with traditional real-time gamma measurement, which is about 40-50ft away from the drill bit. In addition, the sensor units measure bit and string rotation speeds below and above the mud motor, enabling the detection of the motor output rotation speed and motor back-drive dynamics in real time.
Real-time near-bit inclination, advanced drilling-dynamics and geosteering measurements have been provided in a mud motor without compromising mechanical integrity or directional response. The real-time inclination, drilling dynamics data, and pseudo-gamma measurements from the instrumented motor are integrated into our drilling advisory system to enhance the drilling efficiency and wellbore placement accuracy.
Initiate Best Practice through Brilliant Planning and Executing of Drilling Level I Multilateral Horizontal Well in Kuwait to Accomplish Cost Optimization & Land Space Utilization
Authors: AL-Hajri Nasser , Al-Khaldy Ali , Hassan Jassim , Boukhamseen Ali , Dashti Reham , Alotaibi Fahad , Gupta Satya , Chawla Deepanshu 
Published: March 2023

Abstract
Reduced land slots availability for drilling of new wells, operator's focus to increase production, aim to reduce effective cost per barrel and to minimize the environmental footprint, worldwide drilling contractors/operators are looking for various solutions available to address these concerns.
Drilling multilateral wells is one of the solutions to these concerns.
This paper presents the process and steps followed in planning and decision making for drilling a multilateral well in one of the North field in Kuwait, which includes
Identification of filed and understanding formation, Categories of multilateral wells and selection of level and types of multilateral well, Pre requisition of data for level 1 multilateral well, Selection of well slot and reviewing additional tools/service requirement, Selection of well trajectories for multilateral well, Selection of open hole junction point, Selection of section TDs, Review of directional BHA & its suitability for open hole side track, Well control scenarios, Well stimulation plans, Review of Coil tubing (CTU) operation for stimulation and tools requirement, Contingencies plan for reservoir section, Cost saving, higher production, environmental footprint, well completion days.
A Geopolymer System for High Pressure Oil and Gas Well Cementing
Authors: Abdelaal Ahmed , Elkatatny Salaheldin , Abdel Fattah Ahmed 
Published: March 2023

Abstract
There are some technical and environmental issues associated with the usage of ordinary Portland cement (OPC) in well cementing. These concerns persuaded the researchers to search for alternative materials to overcome the technical challenges and to provide eco-friendly cement systems. The use of geopolymer technology is widespread across many industries, particularly the construction sector. Oil and gas well cementing hasn't yet seen a full-scale deployment of it, though. This work evaluates the possibility of using hematite to develop a heavy weight geopolymer system for cementing operations. The biggest challenge in this work was developing a flowable heavy weight geopolymer formulation with good rheological properties and sufficient thickening time. The evaluation included rheological properties, fluid filtrate, strength, petrophysical and dynamic elastic properties for the developed class F fly ash (FFA) hematite-based geopolymer formulation. The results showed that the developed high density geopolymer system possessed acceptable properties making it a possible candidate for different cementing applications.
Combining Nuclear Magnetic Resonance with Deep and Ultradeep Azimuthal Resistivity Images in Carbonate Reservoirs Links Reservoir Structure with Rock Type while Drilling
Authors: Ramadan Osama , Idris Umar , Van Steene Marie , Santoso Gagok 
Published: March 2023

Abstract
Deep and ultradeep azimuthal resistivity images enable precise well placement inside the reservoir structure. However, they deliver limited information about the quality of the reservoir, especially in carbonates, where large pore-size variations are common. Combining the deep and ultra-deep resistivity images with logging-while-drilling (LWD) nuclear magnetic resonance (NMR) measurements enables linking reservoir structure with rock types while drilling for optimal well placement.
The NMR data is used to generate four petrophysical rock types while drilling: RT-1 has good porosity and long T2 components, indicating large pores; RT-2 has good porosity but medium T2 components, indicating smaller pores; RT-3 has medium porosity and long T2 components; and RT-4 has medium or low porosity and medium or short T2 components, indicating the worst facies. The first step in identifying these rock types is running factor analysis on the NMR data. This data analysis method is used to reduce a large dataset to a smaller number of underlying components. Used with NMR data, the method typically produces 9 to 11 factors and their associated poro-fluid facies, which are further reduced to four to ease interpretation.
The method was implemented in two wells. The first had a single lateral, which was geosteered using ultradeep azimuthal resistivity images and NMR. The borehole entered the reservoir from the bottom. The NMR indicated a large section of RT-4, so the well was steered to cross into the upper reservoir lobe in search of better rock type. The best rock type, RT-2, was discovered at 8 ft true vertical depth (TVD) below the top of the reservoir, and geosteering continued within that rock type.
The second well was a trilateral, geosteered with deep azimuthal resistivity imaging and NMR measurements. The initial lateral penetrated the first reservoir layer, where the NMR indicated RT-3 rock type with high permeability. After about 500 ft of drilling, the target reservoir layer was identified below the wellbore, and the well was steered into it. The NMR initially indicated that the rock type was RT-2, but combining the reservoir structure from the deep azimuthal resistivity image inversion with NMR rock typing confirmed that the upper section of the second layer had the best rock type, namely RT-1. Based on this finding, the second and third laterals were placed in the upper part of the same reservoir layer, with an excellent net-to-gross ratio.
Association of NMR rock typing and reservoir structure while drilling is a new methodology that combines the strengths of both techniques to optimize reservoir understanding and well placement.
Successful Introduction of a Novel, High Dogleg Rotary Steerable System
Authors: Sutherland George , Lasater Jeff , Althoff Gary , Verma Jaywant 
Published: March 2023

Abstract
Rotary Steerable Systems (RSS's) have proven beneficial over conventional steerable motor systems, which has driven significant market uptake over the last several decades. Consequently, applications for RSS's have expanded and encouraged RSS technology developers to meet these ever-changing market demands. Modifications to the basic proven RSS methods, attempted independent reproductions of those methods, and other novel methods have emerged to fulfill these market demands.
The initial RSS method and technique were invented and proven in the late 1990s, and common ways of creating wellbore deflection emerged, allowing the industry to attempt the classification of these methods. These classifications were an attempt to gain a better understanding of the advantages and disadvantages of each and help understand where and what version of technology to apply for an ever-increasing expansion of applications.
This paper describes the attempts at classification of RSS's, then addresses the drivers, development, and field trial results of a new method for placing wells using a high dogleg automated rotary steering system (SwR; Steering-while-Rotating).
The SwR was targeted to meet market changes identified in 2016 and projected out ten (10) years by the SwR technical team. Simplicity, fostering reliability and value were major design tenets. A high dogleg curve (20°/100’) design, enabling "one-run, Vertical, Curve, and Lateral" bottom hole assemblies, two-way (uplink-downlink) downhole communications along with autonomous self-steering capability, also drove the SwR development.
The initial SwR prototype system for 8-3/8"-9-7/8" hole sizes was built, and field trials began in Q3 of 2019. The SwR team weathered the global Covid-19 pandemic of 2020-21 with the rest of the world and deployed systems to the Middle East, while also securing and executing trial and commercial runs within North America in 2021 and 2022. Conclusions are based upon, and data is presented from thirty-seven (37) bit runs and the first 50,000 feet drilled with the SwR.
The SwR team has delivered a unique steering method to the industry and presents the early run data demonstrating the SwR technology capability to drill challenging well profiles, in challenging environments. The SwR technology was designed for the RSS market of today and for several years to come improving the value proposition for modern RSS well placement technology.
An Integrative Software Platform to Support Drilling Operations in Troublesome Formations
Authors: Han Yanhui , Liu Chao , Phan Dung 
Published: March 2023

Abstract
A software product, called SAGE-WSA, has been developed to provide an integrative platform for experimenting impacts of various affecting factors and mechanisms on the drilling mud design and wellbore stability. The software packages analytical solutions of stresses, pore pressure, temperature, and chemical potentials around wellbore in both intact and fractured poroelastic media, and many failure criteria, including all often-used ones and some developed in-house. The software provides a friendly user interface for accepting inputs required for the well stability analysis and presenting computed results, such as mud weight window, failure region, stress distribution, etc., in form of charts, contour and spreadsheet. The application and performance of SAGE-WSA is demonstrated through calculating safe mud weight windows for drilling a few troublesome formations. In the low-permeability formations, the timescale of fluid diffusion around borehole is in the same order as drilling operation so the safe mud weight window is time-dependent. Computation shows that the critical mud weight calculated by SAGE-WSA converges to well-known Hubbert-Willis (H-W) solution for impermeable borehole at short time and Haimson-Fairhurst (H-F) solution for permeable borehole at large time. In high-pressure high-temperature formation, the time-dependent pressure diffusion and thermal diffusion are coupled. It is observed that the critical mud weight window is overestimated without considering cooling effect, which may cause formation permeability damage. In chemically active shales, the trouble comes from the chemical activity difference between drilling mud and the formation. In the analysis the poroelastic and chemical effects are coupled. For mud with lower activity, the water will be driven out of the formation and the pore pressure can be dropped significantly. In naturally fractured formations, the natural fractures speed up the diffusion process and degrade the mechanical strength, causing the safe mud weight window much narrower.