bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Experience from Robot Tests on Drill Floor and Pipe Deck
Authors: Raunholt Lars , Meissner Siegfried , Kverneland Ole Gabriel Johan 
Published: December 2021

Abstract
The objective of this paper is to present results from extensive testing of fully robotic drilling and pipe handling operations in the drilling industry, including several robots and tests on both land and offshore.
Throughout the last eight years, all-electric, heavy-duty drilling and pipe handling robots of up to seven tons capacity have been tested and piloted on dedicated test facilities, land rigs and offshore rigs. The robotic equipment includes drill floor robot, pipe handler robot, robotic roughneck and pipe deck robot with the purpose of removing the people from the drill floor, derrick and the pipe deck. The testing and qualification have been conducted in phases and in a cooperation between equipment manufacturer, rig contractors and operating companies.
The industry has great expectations with the introduction of robotics for red zone management and eliminating all 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 robotics systems lower the noise and the carbon footprint due to higher energy efficiency and less GHG emissions. Also, the precise motion control of robots enables digitalization of the drilling process.
The testing of robots in drilling applications has been done with the purpose of testing and qualifying the technology, as well as gaining experience with performance, reliability, maintainability, safety, and value to the users. This paper presents performance data from robot operations including both single robots and full system operations, such as tripping and stand-building. Reliability of electric robots in hostile environment is analyzed with regards to field experience from land rig drilling and offshore operations. Finally, the value to the users is substantiated.
The paper provides unique results and experience from the longest and broadest tests of heavy-duty all-electric robots in the drilling environment. It therefore provides valuable input for decisions of future use of industrialized robots in the oil and gas upstream industry.
Asphaltene Management Leading to Significant Reduction of Production Deferment Through New Technology Trial MFC Tool
Authors: Narwal Tushar , Kumar Kamlesh , Alias Zaal , Agrawal Pankaj , Abri Zahir , Al Hadhrami Abdullah , Al Kindi Abdulbaqi , White John , Asidin Azlan 
Published: December 2021

Abstract
In Southern Oman, PDO is producing from several high pressure (500-1000 bar), deep (3-5 km) and sour fields (1-10 mol % H2S). Over time, wells from one field (S A3) started having asphaltene deposition in the wellbore. Recently, the impact on production became severe resulting in high deferment, increased HSE exposure with plugging and high intervention costs.
Asset team kicked off an asphaltene management project to tackle this problem, with one initiative being a field trial of a new technology, Magnetic Fluid Conditioner (MFC) to avoid/delay asphaltene plugging in the wellbore. This paper discusses the asphaltene management strategy and field trial results from this new tool deployed to prevent/delay asphaltene deposition.
Opportunities and Challenges in Converting Existing Natural Gas Infrastructure for Hydrogen Operation
Authors: Adam Peter 
Published: December 2021

Abstract
Hydrogen holds enormous potential in helping the world achieve its decarbonization goals and is set to play a key role in the Energy Transition. However, two central building blocks are needed to make the hydrogen economy a reality: 1) a sufficient source of emissions-free (i.e., blue or green) hydrogen production and 2) a needs-based transportation and storage network that can reliably and cost-effectively supply hydrogen to end-users.
Given the high costs associated with developing new transportation infrastructure, many governments, pipeline operators, and regulatory bodies have begun exploring if it is both possible and economical to convert existing natural gas (i.e., methane) infrastructure for hydrogen operation. This paper outlines opportunities and technical challenges associated with such an endeavor – with a particular focus on adaptation requirements for rotating equipment/compressor drive trains and metallurgical and integrity considerations for pipelines.
Discrete Fracture Model for Hydro-Mechanical Coupling in Fractured Reservoirs
Authors: He Xupeng , Qiao Tian , Alsinan Marwa , Kwak Hyung , Hoteit Hussein 
Published: December 2021

AbstractThe process of coupled flow and mechanics occurs in various environmental and energy applications, including conventional and unconventional fractured reservoirs. This work establishes a new formulation for modeling hydro-mechanical coupling in fractured reservoirs. The discrete-fracture model (DFM), in which the porous matrix and fractures are represented explicitly in the form of unstructured grid, has been widely used to describe fluid flow in fractured formations. In this work, we extend the DFM approach for modeling coupled flow-mechanics process, in which flow problems are solved using the multipoint flux approximation (MPFA) method, and mechanics problems are solved using the multipoint stress approximation (MPSA) method. The coupled flow-mechanics problems share the same computational grid to avoid projection issues and allow for convenient exchange between them. We model the fracture mechanical behavior as a two-surface contact problem. The resulting coupled system of nonlinear equations is solved in a fully-implicit manner. The accuracy and generality of the numerical implementation are accessed using cases with analytical solutions, which shows an excellent match. We then apply the methodology to more complex cases to demonstrate its general applicability. We also investigate the geomechanical influence on fracture permeability change using 2D rock fractures. This work introduces a novel formulation for modeling the coupled flow-mechanics process in fractured reservoirs, and can be readily implemented in reservoir characterization workflow.
Machine Learning in Computer Vision Software for Geomechanics Modeling
Authors: Noufal Abdelwahab , Sreekantan Jaijith , Belmeskine Rachid , Amri Mohamed , Benaichouche Abed 
Published: December 2021

AbstractAI-GEM (Artificial Intelligence of Geomechanics Earth Modelling) tool aims to detect the geomechanical features, especially the elastic parameters and stresses. Characterizing the wellbore instability issues is one of the factors increases cost of drilling and creating an AI-based tool will enhance and present a real-time solution for wellbore instability. These features are usually interpreted manually, depending on the experience and usually impacted by inconsistencies due to biased or unexperienced interpreters. Therefore, there is a need for a robust automatic or semiautomatic approach to reduce time, manual efficiency and consistency.The range of Geomechanics issues is wide and interfaces with many other upstream disciplines (e.g., Petrophysics, Geophysics, Production Geology, Drilling and Reservoir Engineering). Safe and effective field operation is built on the understanding and implementation of the subsurface in-situ stress state throughout the life of the field; the quantification of key subsurface uncertainties through well thought-out data gathering and characterization programs. The integration with appropriate Geomechanics modelling and the field surveillance /monitoring strategy.There are two major aspects that must be addressed during the design phase of any Geomechanics project. The first and most important is developing a realistic estimate of the expected mechanical behaviour of the rocks and its potential response as a result of drilling. The second is to design an economic, safe well and support method for the determined rocks behaviour. The design process begins with the feasibility study followed by preliminary design, the detail design, tender design and throughout the construction. The design is constantly updated during each phase as more information becomes available and this requires the involvement of Geologists, Engineers and Subject Matter Expert throughout the phases of a project. A central concern for all geomechanical designs is the well-rock interaction, which is not only includes the final state but also the transient effects of the well processes as well as time and stress of the dependent rock properties.The end-to-end workflow to achieve the mechanical earth model is automated, guided and orchestrated with the help of machine learning framework such as recommendation engine for offset well data, prediction of well logs, and optimization for all calibration with existing test results, enabling end users to run sensitivity and scenario analysis so on and so forth.
A Novel IoT-Based Method for Real-Time Detection of Spontaneous Leaks in Pipelines, Gathering Systems, and Offshore Risers
Authors: Grimes Matthew , Rensburg Nico Van , Mitchell Stuart 
Published: December 2021

Abstract
This paper presents on a non-invasive, IoT-based method for rapidly determining the presence and location of spontaneous leaks in pressurized lines transporting any type of product (e.g., oil, gas, water, etc.). Specific applications include long-distance transmission lines, gathering networks at well sites, and offshore production risers. The methodology combines proven negative pressure wave (NPW) sensing with advanced signal processing to minimize false positives and accurately identify the presence of small spontaneous leaks within seconds of their occurrence. In the case of long-distance transmission pipelines, the location of the leak can be localized to within 20-50 feet. The solution was commercialized in 2020 and has undergone extensive testing to verify its capabilities. It is currently in use by several operators, both onshore and offshore.
Integration Success Story in Shilaif Shale Oil from Vertical Pilot to Horizontal
Authors: Alharthi Amena Dhawi , Van Laer Pierre , Brooks Trevor , Goiran Pierre Olivier , Baig Muhammad Zeeshan , Lazreq Nabila , Abdelhalim Hamza , Al Marzooqi Hassan , Coscia Marco 
Published: December 2021

Abstract
The development of unconventional target in the Shilaif formation is in line with the Unconventional objective towards adding to ADNOC reserves. For future optimization of development plans, it is of utmost importance to understand and test and therefore prove the productivity of the future Unconventional Horizontal Oil wells.
The Shilaif formation was deposited in a deeper water intrashelf basin with thicknesses varying from 600 to 800 ft from deep basin to slope respectively. The formation is subdivided into 3 main composite sequences each with separate source and clean tight carbonates. The well under consideration (Well A-V for the vertical pilot and Well A-H for the horizontal wellbore) was drilled on purpose in a deep synclinal area to access the best possible oil generation and maturity in these shale Oil plays.
Due to the stacked nature of these thick high-quality reservoirs, a pilot well is drilled to perform reservoir characterization and test hydrocarbon type and potential from each bench. Fracturing and testing are performed in each reservoir layer for the primary purpose to evaluate and collect key fracturing and reservoir parameter required to calibrate petrophysical and geomechanical model, landing target optimization and ultimately for the design of the development plan of this stacked play. Frac height, reservoir fluid composition and deliverability, pore pressure are among key data collected. The landing point selected based on the comprehensive unconventional core analysis integrated with petrophysical and geomechanical outcomes using post vertical frac and test results. Well A-H was drilled as a sidetrack from the pilot hole Well A-V. This lateral section was logged with LWD Triple Combo while Resistivity Image was acquired on WL. Based on the logging data the well stayed in the target Layer / formation, cutting analysis data for XRD and TOC was integrated with the petrophysical results in A-H well.
Production test results from subject were among the highest rate seen during exploration and appraisal of this unconventional oil plays and compete with the current commercial top tier analog unconventional oil plays. Achieving those results in such early exploration phases is huge milestone for ADNOC unconventional exploration journey in UAE and sign of promising future development.
Data-Driven Spatiotemporal Modeling of Reservoir Pressure Dynamics in a Giant Saturated Oil Field in Libya
Authors: Dwivedi Saumitra , Suzanne Guillaume , Algadban Abdulhakim , Hameed Ibrahim A. 
Published: December 2021

AbstractThis paper aims to explore modern techniques based on artificial intelligence (AI) and data science, in order to produce data-driven workflows to analyze, model, and simulate reservoir pressure dynamics. In this paper, it was investigated a data-driven workflow to model reservoir pressure at any point in space and time from sparse pressure data observed at wells, without building a physics-based numerical model. This workflow was termed as spatiotemporal modelling of reservoir pressure. Spatiotemporal modelling of reservoir pressure was based on a three-step workflow including multivariate analysis of pressure data and relevant explanatory variables (features), pressure modelling and spatiotemporal interpolation. The overall workflow provided a comprehensive method to understand and map the reservoir pressure dynamics using data science tools. Several modelling techniques such as generalized additive models, artificial neural networks and spatiotemporal kriging were investigated for their applicability and accuracy. The workflow was applied to a real oil and gas reservoir case, for which the reservoir pressure prediction accuracy was optimized through a few experiments. The optimum experiment produced highly accurate prediction with a mean absolute error of 26.85 psi measured on the training dataset. Moreover, a portion of data used was kept to evaluate blind test accuracy, which amounted to a mean absolute error of 55 psi, for the optimum case. The proposed data-driven workflow was aimed to improve current methods of reservoir engineering and simulation. The suggested workflow showed high accuracy in reservoir pressure predictions with high efficiency in terms of computational resources and time. Additionally, the proposed workflow was developed using open-source libraries which pose no additional cost to computation, in contrast to extremely expensive industry standard physics-based reservoir simulation software. Finally, this workflow could also be used to model other reservoir variables such as production ratios (Water cut, and Gas-Oil Ratio), contacts (Water-Oil contact and Gas-Oil contact), among others.
Gas Wells with Carbon Steel Completion, Can it Handle Sour Gas Production, Case Study
Authors: Gadelhak Abdelrahman , Yugay Andrey , Pimenta Gervasio , Allah Bux Adeel , Baslaib Mohamed , Jaiyeola Abiodun , Pangesto Yohannes , Yassien Diaa , Al-Badi Mohamed , Ahmed Mubashir , Al-Mahri Noora , Reddy Rathnakar , Al-Eid Bashar , Kumar Niraj 
Published: December 2021

Abstract

Title
Gas wells with Carbon steel completion, Can it handle sour Gas production, Case Study.

Objective/Scope
It is a successful case of producing sour gas (up to 18% H2S and 9.2% CO2) since 2016 wells with carbon steel tubing with maintaining downhole chemical injection of corrosion inhibitor.

Methods, Procedures, Process
During 2014 a group of new wells has been drilled in X giant onshore gas reservoir under ADNOC onshore company operating area to maximize gas production and to meet production mandate. Majority of wells has been drilled within the North and peripheral Area of the reservoir. All wells has been completed with a standard completion with a Top completion (+/-7000 ft.) in carbon steel with downhole chemical injection valve, and a corrosion resistant alloy section below the CIV.
After wells commissioning, high H2S contents were observed (Up to 18%), and Management initially instructed operations to shut in 9 wells and formulated a task force to study the applicable options and analyze the data to ensure asset integrity.
The TF recommendation was to flow the wells with close monitoring of wells integrity, in particular annulus pressure
A comprehensive downhole exercise has been done by

Results/Observation/Conclusion
Carbon steel completion with downhole chemical injection is a validated completion solution for such conditions.

Novel/ Additive information
Clearly, case is as a solid reference for sour gas production using conventional completion, sustaining Long-term production is adding more weight to the case conclusion.
Integration of Concentrating Solar Heat into Oil and Gas Operations for Increased Sustainability
Authors: Carnelli Lino , Lazzari Carla , Passera Tamara , Sartori Chiara , Epoupa Mengou Joseph 
Published: December 2021

Abstract
According to Eni's mission to reach carbon neutrality in the countries where it operates, the development of renewable energy could be a key element in the company's strategy for evolving the business model towards a low carbon scenario. In this context, concentrating solar technology can provide a real solution in order to goal the carbon neutrality. Solar thermal energy could be an alternative source to the fossil fuel in industrial processes and also in the oil&gas sector, where the upstream operations (dewatering, stabilization, sweetening…) require substantial amounts of heat. Usually this heat is easily produced by combustion of natural gas available at the oil&gas site.
Concentrating Solar Heat (CSH) technology allows to produce process heat by using specific collectors that concentrate the solar radiation onto a receiver where a heat transfer fluid is heated at medium/high temperature. A thermal energy storage can be added to the solar field to increase the solar fraction and reducing so the CO2 emissions. The fraction of thermal energy not covered by the CSH plant can be provided by a fossil source that acts as a back-up.
With this in mind, a pre-feasibility study was carried out for the integration of a medium temperature(∼200-300°C) concentrating solar plant with or without a thermal storage system and a back-up gas heater in an oil&gas site located in North Africa. The solar heat partially replaces the duty necessary to the heat exchangers that heat the crude to guarantee the separation from water and best stabilization.
Reflective areas of the solar field and total occupancy, thermal energy production during the year, solar multiple and preliminary evaluations of cost of investment are presented. Obviously, the reduction of CO2 emission increases with the solar fraction but the competitiveness and cost-effectiveness of the integration strongly depend on the local cost of natural gas, the presence of government incentives, CO2 credit tax, etc. In any case the proposed solution represents an important step towards energy transition.
Advanced Remedial Hydraulic Isolation by Perforate and Wash Technique
Authors: Yugay Andrey , Daghmouni Hamdi Bouali , Nestyagin Andrey , Abdulsallam Fouad , Morales Annie , Salem Gamal Yousef , Al Ameri Saleh , Suleiman Ali Yahya , Kumar Sandip , McPherson Daniel , Kjonnerod Andre , Bakri Mousa , ElMobaddr Ali 
Published: December 2021

Abstract
Well Cementing can be divided into two phases – primary and remedial cementing. Primary cementing may have 3 functions: casing support, zonal isolation and casing protection against corrosion. First two functions are commonly recognized while the third one might be a point of discussion, as the full casing coverage with 100% clean cement is not something common in most of the fields. In fact, poorly cemented areas of the casing may become negatively charged and create a zones of accelerated corrosion rate.
This paper is about main role of cementing - zonal isolation. The process of primary cementing assumes that cement slurry is being pumped into the casing and displaced outside. After wait on cement time (WOC) it becomes hard, develops compressive strength and creates impermeable seal that ensures hydraulic isolation. Old and well-known technique, it still remains one of the most challenging rig operations. It is unlikely to find a service company that would guarantee 100% cement displacement behind the casing all the way from top to bottom. Main challenges in this region are quiet common for many other fields – displacement in deviated sections, losses before and during cementing, exposure to pressure during cement settling. In case the main target is not achieved (no hydraulic isolation behind the casing) – we may observe behind casing communications resulting in sustainable pressures in casing-casing annuluses. In this situation the remedial cementing takes place. It's function is to restore isolation so the cement can work as a barrier that seals off the pressure source. Despite of the good number of sealants available on the market (time, pressure, temperature activated) that can be injected from surface to cure this casing-casing pressure, Company prefers not to do so unless there is a proven injectivity capability that would allow for the sealant to reach deep enough, to protect aquifers in case of outer casing corrosion. Otherwise that would be just a ‘masking" the pressure at surface. Therefore in general Company prefers rig intervention to cure the pressure across the cap rock in between the aquifers and the reservoir. Those aquifers are illustrated on the Figure 1 below:
More details on Company casing design, cement evaluation issues, sustained casing pressure phenomena and challenges have been mentioned previously [Yugay, 2019].