bluuebunny/crossref_metadata_2025_split huggingface dataset:
Data Integration of Reservoir Architecture & Petrophysical Properties from Extra-Deep Azimuthal Resistivity Inversions to Optimize Lower Completions Designs
Authors: Mutairi Bandar , Wang Yanhui , Alahmadi Mohammed , Ferreira Enrico , Mumtaz Asim 
Published: October 2022

Abstract
This article proposes a workflow that combines reservoir mapping by logging while drilling (LWD) Extra- Deep Azimuthal Resistivity (EDAR) Inversions, LWD azimuthal bulk density image (ABDI) interpretation and calculation of true formation resistivity (Rt) to acquire an expected permeability index. It helps to understand the architecture of the reservoir while also providing an insight to optimize zone selection to optimize intelligent completions design (ICD) for production enhancement in a timely fashion.
Initially, EDAR inversions provides geostructural information within depth of detection (DOD), which includes apparent formation dip, layer resistivity and pay zone thickness (PZT). It defines cap rock boundaries and fluids contacts while drilling and layer boundaries are subsequently confirmed by ABDI in real time. Structural Inversions based on ABDI interpretation are performed, resulting in calculated Rh and Rv, unaffected from resistivity artefacts of each layer.
The resultant Rt will be used as an input to calculate the permeability index from various formulas. Finally, all outcomes listed above will feed the flow and storage Stratigraphic Modified Lorenz Plot (SMLP) and Modified Lorenz Plot (MLP).
Well Placement in layered thin carbonate reservoirs can result in LWD measurement uncertainties caused by artefacts, such as polarization horns in high angle wells, and therefore induce over-evaluation of a reservoir's flow and storage capacity. SLMP and MLP illustrate potential ICD zonation based on calculated permeability index, enabling identification of high-quality and low-quality productive zones while integrating it with wellbore shape and petrophysical analysis. Additionally, PZT can influence ICD selection due to its influence on maximum storage capacity formula. EDAR inversions change perspective of ICD zones by effectively mapping wellbore position within reservoir architecture and its closeness to fluid contacts.
Available cases of wells drilled in Middle East show that thickness from EDAR effectively changes each zone HC storage capacity, which leads to a different ICD setting to conclude the production workflow. which can result in CAPEX investment inefficiency, increased post-well OPEX, low ultimate hydrocarbon (HC) recovery or water injectivity and extended field development. Henceforward, it can support energy transition applications by ensuring optimum flow in the reservoir with possibility of using sourceless technology, therefore reducing carbon footprint (i.e. geothermal wells).
The value of this approach can contribute to production KPIs and justify the well construction investments at minimum risk by enhancing lower completions design utilizing EDAR technology.
Effective Interbed Multiple Attenuation with Exploration-Scale Seismic Data
Authors: Jia Xueyi , Wang Haiyang , Baumstein Anatoly , Cha Young Ho , Gottumukkula Vijay , Dura-Gomez Inmaculada , Martinez Alex 
Published: October 2022

Abstract
If not properly handled during seismic processing, strong interbed multiples pose serious challenges to seismic interpretation in complex subsurface environments. Conventional data-driven interbed multiple prediction and attenuation (IMA) methods can produce high quality interbed multiple models. However, they also come with technical difficulties in reading, mapping, storing and calculating billions of traces, and have huge computation cost. Thus, multiple runs of conventional IMA for different multiple generating interfaces are not always practical.
A Marchenko-based IMA method can predict all multiples generated from an overburden with two stages, which can significantly reduce the computation cost for complex structures with more than one strong interbed multiple generator. We propose a practical approach to combine the two stages into one algorithm by storing and reusing a common intermediate product, aiming to predict all multiples in one run. With our approach, the runtime for Marchenko-based IMA is equivalent to one run of conventional IMA, making this technology computationally affordable and fitting into industrial seismic processing timeframes.
Synthetic and real exploration-scale seismic data examples will be used to demonstrate how the multiple generation mechanism is identified and the interbed multiples are accurately modeled from an overburden above a user defined horizon and mitigated at the target reservoir level with advanced post-migration domain adaptive subtraction. The results show that the strong migration swings due to interbed multiples can be removed very effectively and efficiently, and aid in subsequent structural interpretation. The proposed Marchenko-based interbed multiple prediction and subtraction approach can be cost-effectively incorporated into an established seismic processing and imaging workflow, providing an additional multiple-free volume for interpretation and well planning.
Automating Trajectory Design in a Cloud-Based Planning Solution
Authors: Suryadi Hendrik Gunawan , Li Haifeng , Jiang Lu , Liu Qing 
Published: October 2022

Abstract
Well trajectory design is an essential part of well planning that affects the entire well design and drilling program. Until today, many well trajectories were designed in a silo by directional service company well planners based on surface coordinates, subsurface targets coordinates, and constraints provided by operators. Geologists also designed trajectories in the geology and geophysics (G&G) applications and then transferred them to well-planning applications. There are many trajectory path possibilities, and the proposed design depends on the designer's experiences. Engineering validation, such as geomechanics, torque and drag, bottom-hole assembly (BHA) tendency, etc., was not checked during generating trajectories and analyzed in different workflows or applications. With the siloed approach and disconnected workflows, trajectory design has become time-consuming because of multiple iterations, discussions, and data sharing. The engineer tries to solve the design constraint and validation issue identified by other workflows one-by-one.
Today, we have various map applications that can design and propose the best route from the start point to the target destination. The application can provide multiple options, including performance indicators such as the shortest distance, shortest time, fewer traffic-lights, or lower cost. Users can also provide some constraints on the proposed route, such as avoiding tolls and avoiding highways.
A new collaborative well planning application was developed in a cloud-native environment, which includes validation workflow. The application can perform automated trajectory design and calculate all possible paths for the given surface location, target location, and other constraints defined by the engineer. Engineers can evaluate every result and select the optimum trajectory based on key performance indicators such as total length, maximum dogleg severity, and kick-off depth.
Additionally, various engineering analysis validations are performed simulatenously, such as anti-collision, hole stability, torque and drag, hydraulics, and BHA tendency. The result is compared with the limit or criteria to give the engineer instant feedback if the new trajectory design causes potential risk in other workflows. The anti-collision analysis is fully automated, from selecting the offset wells, calculating the separation factor, and displaying the result as a traffic light visualization. The cloud-based geomechanics application provides a mechanical earth model that enables auto-validation when the trajectory is created and flags hole stability risks.
In this well construction planning solution, a cross-domain team can collaborate on well-planning tasks simultaneously, with automation that improves working efficiency.
Wellbore Stability Analysis Using Elastoplastic and Thermo-Elastoplastic Approaches
Authors: Hamid Osman , Oluyemi Gbenga , Sanaee Reza 
Published: October 2022

Abstract
Wellbore stability modeling has been known in the oil and gas industry and academia for a long time. The instability-related issues significantly impact field developments, especially in complex deep reservoirs. This instability can substantially jeopardize the drilling objectives, leading to poor wellbore conditions. Most available software uses simple linear elastic modeling approaches to predict wellbore failure and determine the safe mud weight for the planned boreholes. This assumption might lead to inaccurate results.
The main objective of this research is to use an elastoplastic modeling approach to predict a yielded zone around the wellbore using Finite Element Modeling (FEM). These elastoplastic models were used in conjunction with the Drucker-Prager yield criteria.
The yielded zone is interpreted utilizing volumetric strain analysis. The result of this study will be used for any potential breakout development while drilling that might lead to increase wellbore stability-related problems. The damage or yielded zone results will be used for completion packer positioning to avoid pressure communications while packers expand.
These novel techniques will be applied to compute wellbore stability for tight sandstone formation. The methodology can be applied to other locations using the FEM approach.
Minimizing Salt Creeping Through Geomechanics Application and Systematic Drilling Fluids Design in Ultra Deepwater Wells - Operator's First Experience in West Africa
Authors: Zainal Abidin Faieqah , Toha Rozaidi , M. Zin M. Nizam , M. Abdullah M. Baihaky , M. Amin Remy Azrai , A. Razak M Solehuddin 
Published: October 2022

Abstract
In 2017, 2019 and 2021, an Operator drilled 3 ultra-deepwater exploration wells in offshore West Africa. The water depth for well A is around 2900m, well B is around 2800m while well C is circa 2100m. The objective of these wells is to evaluate the potential hydrocarbon accumulation in the subsurface area. Besides the usual challenges being wildcat wells and located far offshore, the wells drilled through pre-salt formations. Hole enlargement due to salt dissolution is also a concern apart from salt movement to close the hole owing to its plastic nature. Furthermore, the lack of offset wells for determining wellbore behavior also caused another challenge. Experiences from the nearby wells showed many signs of wellbore instability such as tight spots and losses.
The common causes of wellbore instability are unbalanced stress dependent on stress change and rock strength, and shale-fluid interaction due to hydration of clays. A geomechanical model was constructed and detailed salt creep modelling was developed.
Well A was drilled until the final target depth with minimal wellbore instability and encountered no losses at all while drilling. Well B which was drilled later, also drilled to the final target depth with very minimal wellbore instability. Well C was drilled with longer salt exposure around 490m. The mud weight selected for all wells also successfully minimized salt creeping. These are strongly evident while drilling and running in casing, no tight spots were encountered. Both wells successfully drilled through salt formation with very minimal salt dissolution.
Through the application of geomechanics and systematic drilling fluids design reduce potential non-productive time (NPT) related to salt plastic movement that could be faced by Operator eventually saving Operator's drilling hours.
Drilling to the Limits. A Step Change in Drilling Operations by Utilizing Innovative Drilling Scrapers Technology Tools Enable to Optimize the Drilling Performance with Low Risk and Saves 1.5 Rig Days Per Well in UAE Onshore Fields
Authors: Bethancourt Roswall Enrique , Sarhan Mohammed , Al Reyami Mazin , Mwansa Peter Levison , Kodiah Basma Naeem , Sam Sneha , Gaurav Anchit , Abdelhalim Khaled 
Published: October 2022

Abstract
Optimization of drilling performance with low-risk technologies has become the main challenge for Abu Dhabi Onshore Operator. This paper presents a step change in the drilling operations with the successful deployment of a proven technology solution (of wellbore clean up scrapers which can be added to the drilling assembly) in the new wells, allowing an improvement of the well's drilling time by 1-1.5 rig days for each well.
Following the successful implementation in Abu Dhabi Onshore pilot wells, deployment of the Scraping While Technology (or, SwD) in the new wells have now become part of the standard operations, bringing in direct savings of 65 million-USD to the Operator.
The proposed innovative application allows to combine the wellbore clean up scrapers for 7 inches liner and 9.625 inches casing as part of the drilling Bottom Hole Assembly (BHA) for the last open hole section (6 inches or 6.125 inches) of the well. The Scraper While Drilling tools are dormant while the drilling activity is ongoing and can be hydro-mechanically activated on-demand by dropping steel balls from surface at the end of the drilling activity. Upon activation, the scraper blades from the SwD tools extend outwards and push against the ID (inner diameter) of the casing or liner. The solution allows scraping the casings and liners across the completion packer setting depths while pulling out of the drilling assembly and thereby leaving the completion interval ready for either recording the cased hole logs or running the completion jewellery. This implementation of the SwD saves the operator between 1 to 1.5 rig days per well by allowing the operator to cancel dedicated clean out scraper run(s).
There is no limitation for Scraper While Drilling deployment with regards to the horizontal hole section lengths. Using the SwD in the drilling assembly eliminates the need for a dedicated well bore clean out conventional scraper run; it also reduces the risk factors by eliminating the pickup, lay down, run in hole, and pull out of hole activities of the dedicated well bore clean out runs with conventional scrapers.
The Scraper While Drilling technology hence revolutionizes a typical well design and its drilling operations by eliminating dedicated clean out scraper runs with conventional scrapers and allowing the operator to drill more wells based on the days saved per well in a long-term drilling campaign.
Successful Deployment of Drill Through Turbine Casing Reamer Shoe in Longest Challenging Intermediate Sections on Abu Dhabi Jack Up Operations
Authors: Biyanni Hanifan Mayo , Gohel Prashant , Jadallah Omar Nazih , Rabis Philippe , Couzigou Erwan , Al Ameri Fahed Salem , Law Callum , Charles David , Robertson Kevin 
Published: October 2022

Abstract
The trial of a turbine powered Motorized Reaming Shoe (MRS) was conducted on two fields offshore Abu Dhabi involving the running of 9-5/8″ casing to planned depths in long intermediate sections. The trials involved running casing in the longest12-1/4″ sections to date on each field.
This paper will elaborate on detailed parameters, Motorized Reaming Shoe features and operating practices recorded while reaming through multiple restrictions with a cumulative length of more than 200 ft, across various formations, successfully running casing to the planned depth.
It will also elaborate on casing cementing and shoe-track drilling operations where MRS were deployed.
Referring to the average NPT duration of similar incidents, this initiative has saved 6 to 7 days of operation (eliminating requirement to pull the casing, perform a wiper trip, and re-run back the casing). This is estimated at an average of approximately 1M$ cost savings per NPT event.
The failure to run casing to section TD with the MRS in one of the trial jobs is also analyzed including detailed operational learnings and design changes that could positively impact running long casing strings in complex wells.
This paper details the technical features and potential benefits of Turbine Powered Reaming Systems, how the trials were conducted and their impact on de-risking casing deployments, with specific reference to application in long intermediate casing sections offshore Abu Dhabi.
Synthesis of Epoxy Resin Based Geopolymer Utilizing Saudi Arabian Volcanic Ash for Primary Well Cementing Applications
Authors: Alanqari Khawlah , Al-Yami Abdullah , Wagle Vikrant 
Published: October 2022

Abstract
Conventional cement production possess huge environmental concerns. Which is considered globally the third largest source of CO2 emissions into the environment. This is due to the decomposition of carbonates that produce around 900 kg of CO2 for every 1000 kg of cement production. As a substituent, geopolymer cement can reduce the CO2 emissions by 80% because there is zero CO2 emissions through the geopolymer cement production. Moreover, Geopolymer cement can be prepared utilizing waste materials such as fly ash. In Saudi Arabia, we have enough volcanic ash to sustain the development of this eco-friendly cement. Furthermore, geopolymer binders show an exceptional mechanical, chemical and environmental benefits in comparison to conventional cement. In addition to geopolymer properties, liquid epoxy resins are known to increase bonding with casing; thus, increasing the wellbore integrity.
In this study, we successfully developed a novel epoxy resin based geopolymer cement utilizing a Saudi Arabian volcanic ash for primary cementing applications for the oil and gas industry. This was done by adding an epoxy resin formulation to the geopolymer slurry. This novel cement shows an excellent strength and good rheological properties with a controlled setting time. The objective of this paper is to detail and explain the synthesis of this cement, geopolymer slurry preparation and epoxy resin formulation. Also, to investigate the effect of adding the epoxy resin formulation to the geopolymer slurry in terms of the final cement strength, thickening time and rheological properties as well as to detail lab testing.
To prepare the epoxy resin based geopolymer, the volcanic ash particles were activated first by a mixture of NaOH, sodium silicate and water. Then, an epoxy resin formulation was added to the geopolymer slurry that contains an epoxy resin along with a curing agent. The amount of the epoxy resin formulation was varied in order to study the effect of adding the epoxy resin into the geopolymer slurry in terms of the final cement's setting time and compressive strength. This was done to develop a cement with excellent strength and controlled setting to assure a right cement placement. In addition, the chemical conditions were evaluated to simulate a variety of downhole conditions to prove the effectiveness of this novel geopolymer composition as a cement for primary cementing applications. The lab testing includes gelling time and compressive strength measurements as well as a chemical analysis of the Saudi Arabian volcanic ash.
First Run of 17 Swellable Packers in Sahil Field with 15 AICV as a First New Technology Trial in ADNOC Onshore
Authors: Yahya Maryam Ali , Alhathnawi Mohammad Ibrahim 
Published: October 2022

Abstract
In south-east field, the normalized number of running swellable packers is 7 to 8 swellable packer, and yet with this number holds up occur and could raise other operational issues. In the Onshore operated field, a designated well was nominated to trial an Autonomous inflow control valve (AICV) which is a technology that improves oil production by reducing unwanted gas and water breakthrough. To have the proper implementation of the trial, the development department required 15 swellable packers to be run in the horizontal hole part of the lower completion to assure segmentation isolation and a proper positioning of the AICV. The requirement was challenging, as it was not experienced in the specified site to run this amount of swellable packers, as each swellable packer could create a force which could cause hold up and even a stuck.
Part of the well planning phase, torque and drag simulation, hydraulics simulations and risk assessments were prepared and analyzed to study and evaluate the possibilities of running the 17 swellable packers along a horizontal hole section. During the execution phase, a proper drift run was in place to provide an indication of a smooth run of the lower completion. In addition to that, to assure well bore trajectory accessibility and suitability for the lower completion, a Mechanical Caliper Log run on Tubing Log conveyed (TLC) was in place. As a contingency during running the lower completion, a remote actuated sleeve was placed at the bottom of the lower completion to avoid having a close system in the hole with no circulation, which could case difficulties in releasing the string in case of any hold up or stuck.
The completion deployment was successful, which was a result of a proper planning and communication from all the parties involved. The combined skills of the Operations and Engineering team was key to the safe and efficient execution of the project as a proper and continues follow up was in place by a high-competent members during the execution phase which assured the completion of the well as planned.
This job was a start to encourage other fields to implement new technologies after evaluating each case separately to get the full benefit of it. In case any high risk/ unexperienced circumstances operations, with the proper planning and study, alternative procedures, processes, and technologies can be implemented to add a bigger value to the organization.