bluuebunny/crossref_metadata_2025_split huggingface dataset:
Wireless Activated Drilling Microchip for Wellbore Temperature Measurement
Authors: Shi Zhaorui , Li Bodong , Gooneratne Chinthaka , Zhan Guodong David 
Published: January 2020

Small-sized drilling microchips become useful and efficient logging devices for distributed downhole temperature and pressure measurement. In this paper, new generation of temperature and pressure microchips are developed. Advanced technologies including micro-size wireless charging and light weight protective material have been used to improve reliability and durability as well as the recovery rate of the microchips. Tests have been conducted both in the laboratory and in the field for evaluation.
During drilling operations, initialized microchips are dropped into the drill pipe while making pipe connections. The microchips travel downwards in the drill pipe and pass through the bit nozzle carried by the mudflow. Then microchips are pushed upwards in the annular section and are eventually recovered at the shale shaker. Distributed downhole parameters such as temperature and pressure measurements are recorded periodically in the memory of the microchip, which can be downloaded entirely after the recovery process.
The lab test result shows the new generation microchip is able to work longer in lower power consumption under simulated extremely harsh conditions. By applying different light weight protective material, microchip can adjust its own density close to the mud density to make it easier for flowing upward in the annular section. This way the microchip recovery rate can be increased in the field. The field test results show an excellent correlation between the measurements and the pump flow rate. The wellbore in-situ temperature profile processed from the microchips could be of significant importance for optimizing cement formulation.
Unlike other downhole measurement method, microchips provide valuable pressure and temperature data in front of the drill bit while drilling. It is an efficient diagnostic tool for identifying problems encountered in drilling process, such as seepage, lost circulation and local overheating. Microchip technology can be considered as an open distributing sensing platform for integrating other sensor units and creating downhole sensor networks, which will be a digital evolution to achieve internet of things (IoT) in oil and gas industry.
Improving the Reliability for Remote Functioned Barrier Valves. A Truly Multicycle, Remote Activated Barrier Valve
Authors: Croucamp Leandre , Munro Christopher , Murdoch Euan 
Published: January 2020

The reliability of subsurface barrier valves has long been an industry problem. This can lead to costly interventions, especially in deepwater subsea markets. This paper describes the world's first deployment of multicycle barrier valves in 2 subsea wells in Australia. These valves use innovative methods of both remote activation and triggering, previously unavailable on the market, to attain a step-change in reliability.
The remote activated barrier valves were deployed as part of a subsea gravel pack system. They were initially run in hole (RIH) in the open position as part of the lower completion, then closed mechanically. The valve was subsequently opened via radio frequency identification (RFID) tags and then closed again mechanically, to allow running of the upper completion. Frequency modulated pressure cycles were applied to the well to open the valve and enable the well to flow.
The valve functioned exactly as planned, and it demonstrated that it could be closed multiple times on a semi-sub vessel. The valve was then opened via RFID tags conveyed on wash pipe. This is a much more reliable method when in high-debris environments. The valve was opened for the final time via frequency modulated pressure cycles. These pressure cycles are better able to be transmitted through debris and are not affected by other hydraulic events in the well.
The hydraulic pump that actuates the tool provides a constant force directly to the ball valve mechanism and is not subject to failures over time, unlike existing gas charges, ratchet mechanisms or springs. The RFID, mechanical or pressure cycles that trigger the valve offer a huge increase in operational flexibility that have never been able to be realized with existing technologies.
New and Advanced PDC Bit Design with Innovative Backup Layout Cutters Helps Extend Bit Life without Sacrificing Rate of Penetration During a Heterogeneous Application, Northwest Kuwait
Authors: Boussahaba Hocine , Sugumar Jayaram , Vrnak Kyle , Benyoucef Lyes , Fadtare Ashish , Al-Shammari Altaf , Al-Failakawi Khaled , Dutta Abhjeet , Al-Khaldy Meshal 
Published: January 2020

The 9 1/4-in. polycrystalline diamond compact (PDC) bit is a unique size necessary for long-interval deep-drilling casing programs in Kuwait. Drilling the section is a major challenge because the long interval consists of nonuniform lithology with variations in compressive strengths, and it contains an abrasive ultra-hard sandstone, a compact hard shale with a low rate of penetration (ROP) performance, and carbonates with shale, oolite, and sand traces. The interval is commonly drilled using either two or three new PDC bits, and extra trips are expected.
Efforts were made to substitute the numerous PDC bit runs with one customized and reliable design that can overcome formation hardness and variations in compressive strength and maintain the same ROP to total depth (TD) with limited success, even though the idea of backup cutters has existed for decades. A new, durable PDC design was implemented with the objective of helping improve the ROPs across all intervals. The innovative backup cutter placement design and minimal critical depth of cut for each primary and backup cutter in the same radial position are the most desirable solutions.
The new and innovative PDC cutters’ distribution structure using the new bit design software coupled with an innovative backup cutter placement minimized the calculated bit wear and maintained the cutters’ sharpness along the entire section without needing an extra trip or a new second bit, which produced the best performance achieved in the northwestern Kuwait fields.
The new bit design achieved the longest footage drilled in Kuwait for a single bit of 9 1/4-in. size with a competitive ROP compared to previous cases. The used bit came out of the well in excellent condition with minimal normal wear.
A case study of an innovative PDC cutting structure layout using the new PDC bit design with efficient backup cutter placement, bit formation interaction modeled to help predict cutting structure wear, and advanced rock mechanics analysis are discussed. The new backup cutters’ layout procedure extended bit life without sacrificing ROP.
Understanding the Limit of Wellbore Cleanliness During Connection Via Theoretical Study and Field Implementation
Authors: Ruzhnikov Alexey 
Published: January 2020

One of the most common operations while drilling is the connection of drill pipes after every stand drilled. The main concern prior and during this operation is to ensure that annulus around the bottom hole assembly (BHA) and drill string is clean of any cuttings, when often excessive time spent to achieve it. This manuscript discusses modeling, field implementation and operational observations of changing the standard practices, what led to significant time reduction while drilling vertical, deviated and extended reach (ERD) wells.
The most common worldwide practice is to wash / ream a stand up and down prior to connection to remove any potential cuttings around BHA. Having this in mind the objective was set to minimize this time as much as possible towards full elimination. To accurately predict the cuttings lifting forces, annulus cleanliness, hook load fluctuations advanced modeling combining torque, drag and hydraulics was developed. The model considers all the key parameters such as drilling fluid density and rheology, BHA configuration, pumping rates, wellbore geometry, temperature and pressure effects, etc. and can estimate the time required to spend at the end of every stand.
A total of up to one hundred jobs were simulated and followed by the field implementation in the different sections, which were ranged by bit size (from 17-in. to 6-in.), inclination and complexity (from zero to 90 degrees, including ERD wells) as well as other affecting parameters such as losses, wellbore stability etc. The data from the initial wells were crosschecked vs available MWD/LWD data (as equivalent circulating density, annulus pressure while drilling, temperature etc.) to confirm the results of the simulations.
As a result, new connection practices were developed with minimum clean out time prior to a connection. Two examples: in the vertical wells the pre-connection time was reduced almost to zero and only two minutes drill-off now done; in deviated wells including ERD a standard approach of washing up / reaming-down a stand was replaced to 2 - 3 minutes drill-off followed by ream up and down of 10 ft only. Together with other changes it not only allowed the decrease a connection time by up to 60% without the negative incidents like stuck pipe, but also minimized impact on the bottom hole assembly (BHA) components happening due to off bottom stick / slip. This resulted in great time savings, where around 2 days can be saved for 20,000 ft wells vs previously applied practices.
The manuscript describes an engineering-based approach to connection practices which allows to shorten well construction time and decrease the well cost without additional risk.
Non-Productive Time Reduction In Overpressured Reservoirs Through Seamless Integration of MPD, LWD And RSS Technologies.
Authors: Amorocho Claudia , Galindo Jhonny , Hernandez Julian , Stich Chad , Valecillos Juan , Oliver John , Scherer Gary 
Published: January 2020

This case study shows a cooperative implementation of managed pressure drilling (MPD), logging while drilling (LWD) and rotary steerable system (RSS) technologies to prevent non-productive time (NPT) while drilling through a section with a tight pressure window in a highly over-pressured reservoir in the US. Drilling risks were proactively reduced by providing real time data transmission for reservoir characterization and identification of critical well sections.
The bottom hole assembly (BHA) was designed to be able to provide high quality measurements according with specific priorities in real time formation characterization and post mortem evaluation. The data transmission was also optimized to be able to monitor the performance of the rotary steerable system (RSS) as well as provide logging measurements that allowed decision making in real time. The implementation of MPD and the continuous monitoring of pressure while drilling (PWD) data allowed to adjust the downhole pressure profile to minimize the impact of drilling hazards by early detecting micro influxes and micro losses reducing considerably their size and impact to control them.
Acquisition and transmission of high-quality logging while drilling data in real time allowed to identify the formations being drilled using Gamma Ray and resistivity logs anticipating the risk associated with each formation. The accurate identification of the pore pressure ramp, a consequence of using real-time MWD GR logging to correlate incoming formation tops with offset data, and the monitoring of the PWD data help to proactively respond to the imminent drilling hazards allowed to drill through these problematic sections using an underbalanced mud weight with the help of MPD which can adjust the pressure profile immediately reducing the risk of NPT. In addition to LWD and MPD technologies, the implementation and monitoring of RSS reduced the risk of downhole mechanical problems. Furthermore, acquired high-resolution sonic and density data from memory provided means to tie together the seismic data, in time, and LWD data, in depth, in order to make accurate predictions of incoming formations tops for future wells. This improved predictive capability to identify the depth range of the pore pressure ramp, while the correlative in-formation log signatures provided robust analysis of offset producing trends.
Drilling scenarios that otherwise deemed unattainable due to the big potential for drilling hazards, can currently be tackled safely while also optimizing capital expenditure through the implementation and monitoring of reliable LWD, MPD and RSS systems. The designed BHA allowed reliable data acquisition and the use of MPD enabled the versatility of instantaneously adjusting the downhole pressure profile leading to a flawless drilling operation with reduced NPT associated to pressure-related issues.
Saudi Aramco Drives Technological Initiatives for Groundwater Conservation In Oil & Gas Production Facilities
Authors: Ahmed Syed A. , Koleshwar Vilas S. , Yousef Khaled K. , Albluwi Saif F. , Owaidhi Sultan H. 
Published: January 2020

This paper describes Saudi Aramco's efforts in conserving groundwater in Kingdom of Saudi Arabia. Driving corporate-wide water conservation initiatives, Saudi Aramco has identified several technologies to pilot test and deploy. One of these initiatives involves the unique idea of treating relatively low salinity produced water, from crude oil desalters at Gas Oil Separation Plants, for use as a wash water stream for crude oil desalting. The concept, known as Desalter Effluent Reuse Technology (DERT), was successfully field-tested and is now being deployed on a commercial scale.
The idea of treating & reusing desalter effluent water as desalter wash water and thereby conserving groundwater, was submitted for US patent on September 29, 2017, and assigned a Serial No. 15/719,884 by the US Patent and Trademark office. Saudi Aramco prepared a roadmap to pilot test several Desalter Effluent and produced water-based water conservation technologies, to deploy at GOSPs where seawater is not economically accessible.
Slimming the Well While Keeping the Well Objective Intact for Cost and Well Delivery Optimization – A Unique Way of Drilling
Authors: Alotaibi Ali , Almulla Jassim 
Published: January 2020

Deep gas wells exhibit characteristics such as high temperature and pressure that present challenges in terms of drilling and completions. To overcome these hindrances and deliver the wells in a timely manner, casing design has been optimized by utilizing the latest cutting-edge technology in the oil and gas industry.
The subject area has numerous multiple reservoir pressures, which can be troublesome when drilling in one hole section. In the past, these reservoirs had to be isolated from each other by introducing casing strings, or take the risk of drilling through transient zones. The formation characteristics are troublesome as well. Starting from shale swelling to fractures. These shales are very reactive and force controlled drilling parameters while closely watching the fluid properties just to mitigate the trouble zone. Too many casing strings means an expensive well and high target well days.
This is a complete review, which will discuss implementation of different technologies in a deep gas well. Advanced bridging agents drilling fluid enabled the well to avoid the operation risks of stuck pipe and optimize the rate of penetration through multiple reservoirs pressures. A 4 ½-in by 7-in completion system capable of 15K hydraulic fracturing was used. Innovative way of locating abnormal pressure formation, even though they are unpredictable.
The paper describes a robust solution to well slimming, utilizing the latest technologies, drilling methods and fluid types, while following the original well plan.
Elements Influencing the Estimated Permeability from Pressure Transient Analysis in Comparison to Measured Permeability from Cores
Authors: Qanadeely Hasan , Al-Mulhim Khalifa , Amin Rana 
Published: January 2020

The purpose of this paper is to demonstrate and explain the factors that can produce notable differences between permeability measured in a laboratory from core analysis and permeability estimated from pressure transient analysis (PTA) of build-up and fall-off tests.The paper presents several synthetic cases to show the variations in obtained permeability using each method, and the contributing factors affecting the outcomes. For calculating effective permeability from PTA, errors in input data such as static, dynamic or pressure/volume/temperature (PVT) fluid data can significantly increase discrepancies. Heterogeneity in reservoir permeability distribution such as vertical reservoir layering (variation in permeability vertically), large scale lateral variation or fractures will also add to the discrepancy between methods. Comparison between the permeability from both sources for the same subject wells will be used to illustrate these factors by interpretation of the data and characterization of reservoir.The primary factor contributing to the differences in permeability is that the one measured from core analysis represents absolute permeability to air or nitrogen in the lab and corresponds to only a small sample (few inches) of the reservoir. However, the calculated permeability from a PTA represents the average effective permeability of the reservoir fluid type within the radius of investigation for that particular test. Hence, each method provides a permeability based on different fluids and volumes of investigation. A methodology that can be utilized to estimate the effective permeability for uncored wells, which usually make out most of the wells in any field, using average effective permeability from PTA will be discussed. Such a method is beneficial for simulation studies that require sufficient knowledge of permeability in each area under study. This method should help in extrapolating the permeability all over the field to get more reliable predictions.Permeability plays a very important role in reservoir characterization as well as simulation. Knowing the permeability leads to the success in the placement of wells and therefore wells performance and ultimate hydrocarbon recovery. Thus, the most accurate determination of the permeability is of extreme importance because it affects the economy of the field development. The paper discusses the factors that can produce differences between measured permeability in a laboratory from core analysis and permeability estimated from PTA and the best practices for correcting and correlating between the permeability to achieve more reliable predictions for reservoir characterization and simulation studies which results in better field development.
Journey Towards the Unconventional Digital Well Factory
Authors: Alqahtani Rawan , Reddy Karri , Albawardi Manal , Havard Maxime 
Published: January 2020

Integrated Well Delivery (IWD) Program also known as Digital Well Factory Program is a large cross-functional transformation effort designed to help unconventional oil & gas operators successfully transition and ramp up from exploration phase to development phase. The purpose of the program is to establish a state-of-the-art integrated well delivery capability (referred to as "agile well factory") leveraging the best practices of the unconventional resources industry as well as the latest digital technologies & tools.
IWD program relies on five fundamental concepts that underpin the "digital well factory" vision: Transparency, Connectivity, Adaptability, Collaboration & Cross-Functional Integration. The program was designed to look at well factory performance from a 360-degree perspective and thus is structured around a comprehensive framework of 6 interdependent building blocks:
Well Delivery Performance Advanced Analytics
Well Delivery Zero-based Process Transformation
Well Delivery Integrated Planning & Scheduling Optimization
Well Delivery Process Agility & Automation
Well Delivery Mobility & Integrated Planning Center
Well Delivery Collaborative Operating Model
The end goal of the program is to evolve the operator’s organization into an agile, intelligent, automated & highly efficient well factory. On the one hand, the program aims at making the company capable of smoothly delivering hundreds of wells per year on schedule and in record time & cost. And on the other hand, it aims at making the operator capable of continuously adapting itself based on lessons learned, data driven-insights, operational challenges, strategic changes, etc.
This paper describes the end state vision of the program, its value, approach, framework, key initiatives, management, as well as recommendations for any operator willing to embark on a similar journey.
A Semi-autonomous Snake Robot to Increase Plant Availability, Lower Maintenance Costs and Improve Safety
Authors: Fairclough David 
Published: January 2020

This paper reports on a project to develop a semi-autonomous snake robot, designed for entry into high pressure combustible gas systems. The project is funded by Innovate UK and is a collaboration between Process Vision and the University of Reading.
Recent advances in robotics are making many inspection and maintenance tasks possible. The objective of the project is to provide a proof of concept prototype that can increase plant availability, by reducing the need for inspection shutdowns. As well as improving safety by reducing confined space working and reduce shutdown durations, as online diagnostics will help shutdown planning and logistics.
If internal inspections could be performed without the need to shut down this would:
Reduce downtime and increase efficiency in production
Reduce OPEX
Provide a safety benefit by reducing confined space working
Provide an environmental benefit by reducing the gas sent to flare to de-pressurise
Reduce fixed costs
Allow fewer man hours in inspection tasks
Remove the need for purge gas – nitrogen or air
Reduce the number of procedures required
Reduce the amount of paperwork