bluuebunny/crossref_metadata_2025_split huggingface dataset:
Novel 3D Reservoir Characterization Approach in High-Angle Wells by Means of Multiphysics Integration of Seismic and Advanced LWD Ultra-Deep Resistivity Inversions
Authors: Camara Salim Diogo , Etchebes Marie , Alexander Malcolm , Akindipe Tunde 
Published: December 2021

Abstract
Historically, reservoir characterization in horizontal wells is accomplished through an integrated approach, combining geophysical evaluation and geomodelling with petrophysical assessment. However, the challenge consists of decreasing geomodels’ uncertainties to enable optimal trajectory to reach the sweet spots. Moreover, the main inputs of subsurface representation derived from measurements have their own spatial resolution and scale. For an effective multiphysics integrated approach, a technology capable to bridge from high-resolution borehole data to large scale seismic is required. This communication describes an innovative method to improve the delineation of reservoir geometry and properties surrounding high-angle wells. The novel procedure is divided into three stages. The first focuses on structural delineation using seismic attributes. The second uses advanced resistivity inversions from LWD very-deep directional resistivity tool to provide 3D mapping of the structure and fluid distribution. The third stage integrates the previous steps to build a comprehensive 3D reservoir model with high accuracy, tens of feet away from wellbore, while honoring the geological context and actual spatial resolution of measurements from borehole level up to seismic scale.
The three-step methodology was successfully conducted on the horizontal section of an appraisal well. The automated seismic extraction workflow on the near and far angle-stack seismic cubes is used to interpret the main stratigraphic and tectonic events around the well vicinity. Within the drilling operation, the high-definition resistivity volumes are obtained from a special 3D interpolation of the 2D LWD EM azimuthal inversions, derived from the measurements of the very-deep directional resistivity tool. Such 3D resistivity mapping is used to determine lithological and structural features over tens of feet away from the wellbore. Then, by applying an integrated approach, key geological structures and detailed internal reservoir architectures were revealed, such as the throw and azimuth of a main fault and the spatial variations in lithologies within the reservoir zone. Finally, the respective workflow can be fully applied while drilling, enabling both the complete 3D reservoir mapping but also supporting strategic geosteering decisions to optimize the extension of the net-pay exposure.
Using an Adjustable Cone Meter to Measure Wet Gas
Authors: Mahalingam Sakethraman , Munro Gavin , Arsalan Muhammad , Gawski Victor 
Published: December 2021

Abstract
A traditional fixed size Venturi meter has a turndown of about 8:1 under dry gas conditions that may drop to as low as 3:1 under wet-gas flow. When the well conditions change, a replacement of the original Venturi meter with one of a different size is needed. In this paper, we present the design, development and testing of an Adjustable cone meter that has the ability to adapt itself to the flow conditions automatically and provide a turndown of as much as a 54:1 under dry gas conditions and as much as 20:1 under wet-gas conditions. The patented feature of the Adjustable cone meter is the adjustable sleeve that moves over the cone when the flow rate decreases below a preset value causing an increase in the differential pressure across the meter. In addition, traditional Venturi meters have only one differential pressure measurement and the sensor tends to overestimate the flow when there is liquid present in the flow (wet-gas). The Adjustable cone meter has two differential pressure sensors and the second measurement is used to estimate the liquid content in wet-gas. Two meters were manufactured and tested at the National Engineering Laboratory in East Kilbride, Scotland under gas flow rates of up to 18 MMscfd. Based on the differential pressure measurements under varying flow conditions, algorithms were developed to measure the dry gas and liquid fraction. An over-reading model of the meter and a liquid fraction estimation model based on the pressure loss ratio was derived from an additional differential pressure measurement. The model was used to not only to quantify the gas and liquid flow rates but also the estimated error in each measurement. The measurements show that the Adjustable Cone meter is able to provide low uncertainty in both dry and wet gas conditions and met the conditions outlined in ISO 5167-5. The Adjustable cone meter is a much needed innovation in the area of differential pressure measurement.
Manuscript Title: Characterization of Microannuli at the Cement-Casing Interface: Development of Methodology
Authors: Ogienagbon Adijat , Khalifeh Mahmoud , Yang Xinxiang , Kuru Ergun 
Published: December 2021

Abstract
Formation of microannuli at the interface of cement-casing can create well integrity issues. X-ray CT and Optical microscopy are technological trends that may have potential for direct visualization of microannuli. CT has an advantage of providing non-destructive visualization of microannuli, but its resolution suffers with increase in casing thickness. Conversely, Optical microscopy has the potential of providing higher resolution needed to detect smaller sized microannuli; however, information about microannuli is limited to only a few sections where samples have been sliced. The objective of the current article is to describe a methodology to examine the interface of cement-casing. Experimental work was combined with literature review. This includes both direct visualization methods, evaluation of current trends to better understand the characteristics and geometric variation of relevant leakage paths. We generate test specimens consisting of cement plugs, various steel casing thickness and nano-coated aluminium casings. Hydraulic sealability tests were conducted by injecting water at the cement-casing interface. Flow rates are then interpreted in terms of microannuli aperture and direct visualization of the cement plug-casing interface by CT and Optical microscopy was implemented. The experimental findings of this article will form a basis for studying geometry and size of microannuli as well as modelling of fluid migration.
Integrated Asset Modeling for Deep Gas Reservoirs. Case Study in UAE
Authors: Basioni Mahmoud A. , Al Jefri Abu Baker Ali , Al Blooshi Ahmed Yahya , AlMesmari Hamda J. , Azoug Youcef , Belova Natela , Bogachev Kirill , Grishin Aleksei , Elmahdi Ahmed Mahmoud , Roncarolo Fabio 
Published: December 2021

Abstract
The primary objective of reservoir management is the maximization of plateau duration and reserves recovery, while minimizing the project risks and maintaining the highest environmental and safety standards. It is critical to identify upfront all the risks and bottlenecks that may occur through the entire life of the assets, to prevent them from happening or minimize the reaction time in case of occurrence. Integration of all asset elements (subsurface dynamic models and a surface facility network) provides a fit-for-purpose tool to optimize assets development. This article describes fully coupled surface and subsurface modeling done for 6 reservoir formations (3 fields) sharing the surface facility and including 6 gas reservoirs with different PVT properties. A fully integrated model describes all technical processes occurring in the subsurface and surface systems and has to be further calibrated using measurements done as per the reservoir monitoring plan.
Geothermal Production from Existing Oil and Gas Wells: A Sustainable Repurposing Model
Authors: Molina Oscar Mauricio , Mejia Camilo , Tyagi Mayank , Medellin Felipe , Elshahawi Hani , Sujatha Kumar 
Published: December 2021

Abstract
The geothermal energy industry has never quite realized its true potential despite the seemingly magical promise of nonstop, 24/7 renewable energy sitting just below the surface of the Earth. In this paper, we discuss an integrated cloud-based workflow aimed at evaluating the cost-effectiveness of adopting geothermal production in low to medium enthalpy systems by either repurposing existing oil and gas wells or by co-producing thermal and fossil energy. The workflow introduces an automated and intrinsically secure decision-making process to convert mature oil and gas wells into geothermal wells, enabling both operational and financial assessment of the conversion process, whether partial or complete.
The proposed workflow focuses on the reliability and transparency of fully automated technical processes for the geological, hydrodynamic, and mechanical configuration of the production system to ensure the financial success of the conversion project, in terms of heat production potential and cost of development. The decision-making portion of the workflow comprises the technical, social, environmental factors driving the return on investment for the total or partial conversion of wells to geothermal production. These components are evaluated using artificial intelligence (AI) algorithms that reduce bias in the decision-making process. The automated workflow involves assessment of the following: Heat Potential: A data-driven model to determine the geothermal heat potential using geological conditions from basin modeling and data from offset wells.Flow Modeling: An ultra-fast, physics-based modeling approach to determine pressure and temperature changes along wellbores to model fluid flow potential, thermal flux, and injection operations.Mechanical Integrity: Casing and completions integrity and configuration are embedded in the process for flow rates modeling.Environmental, Social, and Governance (ESG): A decision modeling framework is setup to ensure the transparent validation of the technical components and ESG factors, including potential for water pollution, carbon emissions, and social factors such as induced seismicity and ambient noise levels
The assurance of key ESG metrics will ensure a viable and sustainable transition into a globally available low-carbon source of energy such as geothermal. Our novel cloud- based automated decision-making environment incorporates a blockchain framework to ensure transparency of technical-related processes and tasks, driving the financial success of the conversion project. Ultimately, our automated workflow is designed to encourage and support the widespread adoption of low-carbon energy in the oil and gas industry.
Efficient and Comprehensive Integrity Diagnostics for Dual Completion String Wells, Using Spectral Noise Analyzer Tool
Authors: Baharum Zurailey Bin , Rourke Marvin , Muhadjir Alan Aulia , Andono Widyanto , Zakaria Eva Sarah Binti , Hamzah Suzie Binti , Hademi Noor Rohaellizza Binti , Hamdan Nurul Aida Binti 
Published: December 2021

Abstract
Well operators often face various technical challenges when intervening and repairing older, mature field wells. The most common problem associated with aging wells are tubing and casing integrity. Uncertain sources of downhole leaks and data ambiguity often lead to incorrect diagnostics that can hinder repair work or even contribute to additional or worsened integrity issues. Operators continuously challenge service companies and technology providers to drive innovation. One such challenge is in finding efficient and comprehensive integrity diagnostics for dual-string wells.
A basic and general diagnostic method to verify well integrity in dual-string wells involves setting plugs in the long and short strings and pressure testing the tubings. These operations are generally time consuming, and the test data does not usually pinpoint the location of the leak, if any. Since 2016 a new diagnostic solution for this challenge has been implemented using a slickline-deployed passive acoustic logging technique. Carefully designed intervention planning, combined with efficient data acquisition, led to significant time saving and improved data quality.
A more complete assessment of the integrity of both strings is now more frequent and often necessary, while challenging the conventional thinking of having to assess the lower string only while assuming the upper string is in good condition. However, investigating dual-string integrity with uncertainty on the source of leak, restrictions on facilities and limitations on surveillance time will often waste more time and money if not approached carefully.
This paper discusses two case studies, including a dual-string oil producer in the South China Sea that had sustained pressure in production casing annulus. The well operator initially considered that the long string had an integrity issue, while the short string did not, based on their surface-based annulus pressure diagnostics. Consequently, the operator decided to diagnose only the long string. The passive acoustic memory tool. combined with a fast-response temperature and spinner used for the diagnosis, identified a possible short string leak while logging through the long string. This result clearly demonstrated that surface analyses can be misleading, and a comprehensive downhole diagnostic should be the recommended method to identify leaks, especially in dual-string completions.
This well operator has completed more than 100 integrity diagnostic runs in the last five years. The passive acoustic diagnostic interventions have resulted in an average 50-percent time saving compared to legacy methods, and data analysis results have led to significant improvements in well productivity.
Outcrop Analogues to Fractured Reservoirs, UAE
Authors: Noufal Abdelwahab 
Published: December 2021

AbstractFractures were not the focus of reservoir studies in Abu Dhabi for the last decades, although its importance in enhancing production, as the general understanding considering fractures are not contributing to production. The fractured carbonate outcrops provide useful analogue observations, data and concepts to support subsurface hydrocarbon reservoir characterization from well and seismic data. The fracture orientation, size, porosity, length, spacing, crosscutting relationships, fracture density versus lithology and bed thickness and connectivity are difficult to measure directly from subsurface well and core data. The understanding of fracture formation and distribution and their effects on fluid flow has been greatly improved by the use of outcrop analogue data through the current work.This paper address the fracture geometry, kinematics and mechanical properties based on outcrops matching Abu Dhabi subsurface reservoir analogues. Integrating outcrop data with fracture orientation and fracture density from core and borehole image data, and seismic capturing fractures characteristics. The outcrop analogues constrain the uncertainty and developing new concepts in characterizing the interplay of rock matrix and fracture networks relevant to fluid flow and hydrocarbon recovery. Analysing the fractures with fracture lengths, aperture, spacing per each interval and relate them to the tectonic event are extracted strictly in the reservoir section.The results showing developed highly dipping shear fractures with short length, small spacing and bimodal aperture distribution that related to fracture orientation. Fracture porosity is dependent on size and controlled by lithology, bed thickness, paleostress and rock composition.Understanding fractures and their behaviour will optimize production greatly and they create exploration targets in otherwise tight reservoir zones, including under-explored sections.
Adding Extra Dimensions for Completion Consideration: Case Studies with Geoengineering, Measurement While Pumping, and Data Mining
Authors: Liu Yuan , Mu Lijun , Zhao Zhengfeng , Li Xianwen , Enkababian Philippe 
Published: December 2021

Abstract
Well completion has evolved rapidly in the past two decades, as multistage completion has become the predominant practice to complete a well in many places. Although innovation in completion tool technology has been continuous in recent years, there are still gaps in the well completion optimization practice. In this paper, we add additional dimensions to well completion technology by incorporating geoengineering, measurement while pumping, and data mining, and we have evidence to show that those additional elements help to improve our understanding, on-site efficiency, and overall performance.
Multistage completion optimization is about where and how to complete a well. Different methods were employed in the past, and even with a better-engineered completion design where both reservoir and completion quality are honored, there are still area for improvement. For example, 1) geological properties are not qualitatively utilized in the completion design; 2) real-time operational feedback during the execution phase is inadequate for in-time decisions for completion and fracturing adjustment; 3) the completion-to-well-performance cycle is so long that the learning curve is not fast enough, and too many influential factors are hidden in the details.
Three extra dimensions were added to address the improvement areas. Geoengineering adds "space information" in enabling geological properties from a 3D space grid to be projected onto the wellbore as geology quality (GQ) so that the information can be used together with reservoir and completion quality (RQ and CQ) quantitatively to improve the fracturing treatment design. Measurement while pumping (MWP) adds "timely feedback" in that real-time operational feedback—either from the wellbore via high-frequency pressure monitoring or from the target zones via microseismic data in offset horizontal monitoring wells—can help with the completion and fracture diagnosis and decision making on-site. Data mining adds "pattern recognition" in that reservoir and operation data are collected and analyzed to generate a systematic understanding of the reservoir complexity, paving the way for the improved planning of future well completions in the same region. Each of the solutions comes with specific case studies in our work.
Geoengineering, MWP, and data mining add three dimensions to the current well completion practice. In our case studies, these approaches have demonstrated the capability to improve the accuracy of the design, increase confidence in the execution, and accelerate the learning curve from evaluation. The extra dimensions added to the current completion practice are essentially space, time, and pattern, and together, they help to define the direction of future innovations for completion optimization.
Bioremediation of Cutting Pits by Autochtonous Bacteria-Fungi Consortia
Authors: Carpani Giovanna , Pietrini Ilaria , Baric Massimiliano , D'Ambrosi Francesca , Cova Carlo Alberto , Akhtar Jahanzaib , Buffagni Melania 
Published: December 2021

Abstract
The aim of this work is to verify the potential of a consortium of autochthonous bacteria and fungi, isolated from samples of contaminated soils and water collected in a site containing cutting pits muds, in order to evaluate enhancing in biodegradation of hydrocarbons content. This innovative technique would take advantage of the synergistic effect of bacteria and fungi. In addition, this technique would allow to avoid the introduction of commercial allochthonous microflora for soil remediation and the use of chemical products for tool cleaning.
Samples retrieved from a production site were used to isolate bacterial and unicellular fungal species able to grow on hydrocarbons were demonstrated to be able to degrade light and "diesel-like" hydrocarbons under laboratory conditions and in liquid cultures in less than a month. The activity of the consortium was also tested on crude oil, showing an overall degradation of the analyzable fraction greater of sixty percent after a 14-day incubation. Low C number linear hydrocarbons were the preferred substrate, but also cycloalkanes and mono- and di-aromatics seemed to be a good growth substrate. Probably, the action of enzymes secreted by fungal strains could enhance the degradation of complex molecules such as polycyclic aromatic hydrocarbons.
Lab tests of consortium efficiency on mud samples are ongoing and an on-site pilot test is foreseen, to prove the activity of the consortium under the challenging field conditions. The development of fungal and bacterial consortia for degradation of complex hydrocarbon mixtures will represent an innovative approach that combines the action of enzymes secreted by fungi followed by the bacterial breakdown, a synergistic effect which could potentially increase the rate and effectiveness of hydrocarbons decontamination.
Impact of Fit-for-Purpose Monitoring on EOR Planning
Authors: Moreno Jaime Eduardo , Liu Yunlong , Talabi Oluwale , Gurpinar Omer , Kristensen Morten , Goh Gordon Kim Fah , Paydayesh Mehdi 
Published: December 2021

Abstract
Challenges in the design of efficient EOR field pilots have been discussed and documented in the industry, particularly when it comes to optimization of monitoring plans for technical and economical perspectives. This paper explores the benefits of pilot planning where the monitoring/control strategies are included in the early stages of the design to reduce risk of measurements ambiguity and ensure good quality pilot results evaluation. It addresses the use of new and existing technology in monitoring by highlighting the advantages and challenges of each alternative including potential pairing of complementary options to achieve the pilot objectives including illustration of the use of continuous and sporadic measurements on the evaluation.
The proposed approach starts with a review of reservoir performance, heterogeneity and pilot objectives to ascertain the plausible monitoring technologies/strategies to aid during the pilot de-risking, followed by the identification of adequate novel and mature monitoring options, which are specific to EOR type and measurement nature (permanent, time lapse, etc.). Advantages of incorporating the monitoring strategy as integral part of the pilot design, as well as evaluation of the effectiveness/viability in the presence of uncertainty of the selected monitoring alternatives are discussed providing a reference of suitable/plausible EOR specific technologies. The paper illustrates the importance of selecting monitoring alternatives that feed off each other and the importance of using fit-for-purpose evaluation algorithms and a digitally enabled, structured approach to analyze and democratize pilot results and enable actionable decisions in operations.