bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Laboratory Study to Develop Co2-Foam Formulation for High Temperature and High Salinity Carbonates Reservoirs in Abu Dhabi
Authors: Guillon Valentin François , Gland Nicolas , Odier Celeste , Delamaide Eric , Almesmari Ali Hassan , AlSumaiti Ali M. , Masalmeh Shehadeh K. 
Published: October 2022

Abstract
Specifics challenges for chemical enhanced oil recovery (cEOR) exists in high temperature and high salinity carbonate reservoirs in Abu Dhabi especially with intermediate to high permeability range (10 – 100s mD). CO2-Foam process was investigated through a careful laboratory approach. This involves extensive laboratory work including coreflood experiments to select the most effective process in terms of foam characteristics and behavior.
Foam formulations in various brine (sea water, formation brine) were selected based on a workflow relying on bulk measurements such as solubility, stability, foam properties with/without oil, and solubility robustness versus brine and temperature variations. Sandpack tests were conducted to characterize the foam rheological behavior of various formulations at various gas fraction.
A formulation based on formation brine was then selected. Coreflood on restored reservoir cores were conducted to fully characterize its behavior toward interstitial velocity and gas fraction variation in porous media without crude oil. CO2 foam behavior in reservoir core was finally investigated in presence of oil.
The selected CO2 foam shows promising foaming behavior for such harsh conditions. It exhibits a usual shear-thinning behavior in porous media showing promising mobility reduction factor (MRF) at in-depth interstitial velocity. Critical shear-rate was observed in sandpack experiments.
High quality foam forms only for higher velocity and is maintained when velocity is decreased. This critical interstitial velocity in 40 mD reservoir cores is very low (below 0.3 ft/day) whereas it is above 20 ft/day in the higher permeability sandpack. The behavior toward gas fraction shows a stable MRF from 0.5 to 0.8-0.9 with a critical Fg between 0.8 and 0.9.
Foam behavior in presence of oil was evaluated in reservoir cores. Though foam quality is significantly impacted by oil, foam was found to form. Comparison of alternate injection and co-injection shows the necessity to fine tune slug sizes in case of an alternate injection to ensure a lasting foam.
A significant selective mobility reduction (SMR) was observed when moving from high permeability sandpack to intermediate permeability reservoir cores. CO2-Foam mobility reduction increases by an order of magnitude with the permeability, showing higher MRF in high permeability.
This applied laboratory study on intermediate permeability, high temperature, and high salinity carbonate core sample shows that a foaming formulation was found in such challenging conditions. This formulation in formation brine was proved to develop foam at low shear-rate with low MRF at reservoir conditions in reservoir cores and a high MRF in high permeability sandpack. More work is still needed to increase the resistance to oil and evaluate the SMR effect in reservoir cores.
Gas Kick Well Control Situation in High-Temperature Well Managed with Oil-Based Mud and Managed Pressure Drilling Technology
Authors: Spagnolo Salvatore , Giubertoni Matteo , De Bonis Emanuele , Cavagnero Giovanni , Sirugo Arianna 
Published: October 2022

Abstract
A gas kick in high-temperature well drilled with oil-based mud represents a significant challenge, as the understanding of physical and chemical interactions play a substantial role in the interpretation and decision-making processes.
This work provides theoretical and physical explanations for the multiple phenomena observed during an actual well control event, and their impact on the interpretation of the well behavior. Moreover, this paper provides useful insights on the additional capabilities offered by the usage of the Managed Pressure Drilling (MPD) technology in managing a gas kick.
A peculiar well control situation occurred in a MENA exploratory well while drilling the 12 1/4" x 13 1/2" section. The particular wellbore features such as high-temperature conditions, gas bearing reservoir layers and oil-based mud, all contributed to make the management of the dry gas influx more challenging and difficult to interpret.
Several procedures were needed to regain the control of the well, that was complicated by the effects of oil-based mud thermal expansion, gas solubility and diffusivity principles. Managed Pressure Drilling System (MPD) was also deployed to manage the influx, with a non-conventional dynamic pore pressure evaluation performed during the well control situation.
The uncommon conditions in which the kick occurred, made the interpretation of the well data particularly challenging. The paper will present a detailed engineering analysis and data interpretation required to manage in a safe and efficient manner a gas kick during well construction operation via the understanding of the interaction between multiple phenomena like gas migration, oil-based fluid thermal expansion and oil compressibility, gas diffusivity and solubility. In the presented application, MPD technique is displayed as an added value useful to better understand the well behavior and drive the decision of the required kill mud weight needed to regain control of the well.
Since geological uncertainties are likely in an exploratory context, and high temperature conditions with oil-based mud may exacerbate the risk of a kick due to the Equivalent Static Density (ESD) reduction caused by thermal expansion, the paper will provide the tools and principles needed for a thorough understanding of the wellbore behavior in similar situations.
Successful Implementation of Nanoparticle Deformable Sealing Polymer to Eliminate Differential Sticking of Zeit Sand- A Case Study from Gulf of Suez
Authors: Eissa Amr , Mamdouh Ahmed , Abdelrazik Mohamed , Abdel Maksoud Ashraf , Ouda Abdallah , Hamdy Ahmed , Farouk Mohamed , Ibrahim Lotfi , Salama Ayman , Saber Ragab 
Published: October 2022

Abstract
This paper will describe a successful application of Nano deformable sealing polymer to mitigate a high risk of differential sticking while drilling weak sand of Zeit formation with 17.2 ppg mud weight with overbalance up to 2,500 psi. While trying to combine Zeit and S.G formation with 17.2 ppg mud weight. Two cases in offsets had differential sticking that resulted in well re-spud and isolate Zeit formation by casing string. In the subjected well, it was deeper, so it was impossible to sacrifice casing string to mitigate differential sticking. Application of Nano deformable sealing polymer to decrease the pore pressure transmission by filling the interspaces between bridging material and greatly improve the quality of the filter cake to be thin and impermeable. In addition to drilling fluid enhancement, the condition of the differential sticking was analyzed and improvement in the BHA contact area, BOP stack configuration, and well profile. In this paper engineering principles, laboratory tests of chemicals and actual field results of these improvements will be presented.
It was the first time to use Nanoparticles in the Gulf of Suez, extensive laboratory tests and simulation modeling was performed to formulate the right bridging material and Nanoparticles concentration that fit the characteristics of Zeit sand. The bridging material was decreased from a commonly used value in the field of 50 lb/bbl to 20 lb/bbl to decrease the filter cake's thickness while achieving an HTHP value of less than 2 ml/30 min and spurt loss of zero. PPA test was performed daily during the execution phase that reflected the optimum quality of the actual sample filter cake and also matches the laboratory test performed in the planning stage. In case of a well control event, the BOP stack was supported by a back annular to continue reciprocation of the drilling string while repairing the main annular element if failed. BHA contact area was decreased by optimizing the directional plan to keep a low angle across Zeit sand and by minimizing BHA’s un-stabilized length.17-1/2" hole was drilled successfully using 17.2 ppg mud weight without any issue relating to differential sticking even after losses experienced in Zeit sand.
Due to the successful application of Nano deformable sealing polymer and engineering approaches, it was the first time in GOS to drill Zeit sand with mud weight of 17.2 ppg successfully saving one section in the well design and achieving the well objective. The work described in this paper will help in drilling high permeable sands with a high value of overbalance while eliminating the risk of differential sticking.
Reduce Collision Risk and make Informed Decision with Cost Effective Well Placement Database for Abu Dhabi Exploration Blocks
Authors: Iabbassen Nabila , El Youssef Bassem , Al Shamsi Arhama Rashed , Al Marzouqi Muna Salman 
Published: October 2022

Abstract
The well-collision-avoidance management principles in this paper are a summit of the work and guidelines of industry specialists from both oil operating companies and directional drilling service providers. This well-known subject in the drilling domain, the objective is to drive further the standardization of the collision avoidance rules and process in Abu Dhabi and throughout the industry to improve the efficiency and reduce the related errors.
The results of an unplanned crossing point with an existing offset well can extend from economical loss to a blowout and HSE disasters and even loss of life. well-collision avoidance principles include rules that decide the allowable well separation, directional drilling, and surveying planning in addition to quality check/ quality control procedures. The appropriation of a particular minimum-allowable separation rule does not guarantee a low collision probability. Numerous other components contribute, such as the level of compliance by office and field personnel with collision-avoidance standards and procedures, and the quality and accuracy of the directional surveys database. All these variables are linked and affect the collision risk rate.
The paper is split into many sections, each managing a specific component within the collision-avoidance process. Illustrations are displayed to highlight a good implementation of the process. This adjusted approach will improve the current practice by cover few gaps as currently only ADNOC Drilling Code of Practice Volume 3 Chapter 08 – Collision Avoidance (ADCOP V3CH08) is the unified document used by the operating companies as reference to drill safely in Abu Dhabi, but each company has it’s specific database without common database among all companies drilling in the same city.
The Benefits of an Integrated Approach (Development, Completion, Production Operation, and Integrity) for Gas-Lift Design on an UAE Offshore Field
Authors: Dwivedi Vibhuti , Al Zaabi Fatema , Jaffres Benoit 
Published: October 2022

Abstract
Gas lift design and optimization contributes to one of the key focus areas of whole production optimization value chain. There have been numerous methods and best practices which goes into design of a successful Gas Lift well as well as established industry best practices for the optimal operations of wells and network (facilities), but still gas lift designs derived for present or future well conditions, fail to respond to every possible operating scenario and end up multipointing, slugging or sub-optimal orifice injections.
Well completion and well Integrity are two other important focus areas which are independent from gas lift design but possess major challenges to any gas lift well. During completion of a gas lift well, traditionally GLM (Gas Lift Mandrels) carrying dummy valves are run in hole, to allow for setting packers and testing the tubing/annulus strings. These dummy valves require numerous slickline operations to be retrieved and replaced with live IPO (Injection Pressure Operated) and orifice valves, to be able to gas lift. Depending on the well completion complexity (depth, deviation) and number of gas lift valves, slickline operations performed via rig or barge may require up to 3-5 field days. Since GLV replacement operation requires the use of kick over tools, they are susceptible to incur heavy NPT's and associated HSE risks (Slickline and wireline operations accounts for major carbon footprints in upstream segment).
During gas lift operations, high pressure gas injected into casing possess enormous risks to nearby wells and surface facilities in the event of uncontrolled annulus gas leak from a single barrier envelope. Operating a gas lift well below MAASP (Maximum Allowable Annuus Surface Pressure) remains a challenge in assuring the well is operating within its integral envelope. At times it also leads to deferred production should the well needs suspended production in the event of SAP (Sustainable Annulus Pressure) or workover caused by compromised well integrity.
In this technical paper, authors will attempt to provide a holistic view of a successful Gas Lift well design by addressing the challenges raised (as above) in different phases and emphasizing on the design approach and technical solutions which were implemented, and benefits realized in terms of optimal gas lift operations, rig/ barge days and deferred production saved.
Making Non-Metallic Downhole Tubulars a Reality - Challenges & Way Forward
Authors: Hijles Ali , Waluyo Fauzia , Goh Serena L. M. , AlAdawy Ahmed , El Shamy Omar 
Published: October 2022

Abstract
Non-metallic pipelines are slowly replacing steel tubulars especially in Oil and Gas industry as part of the mitigation strategy to have "corrosion-free" systems, longer life service and lower total cost of ownership. In this paper, authors attempt to provide a discussion of value proposition, technology status quo and future trends, focusing on system challenges on downhole applications, and proposed way forward to build the lacking ecosystem essential to deploy non-metallic tubular downhole.
A brief discussion on current technological advancement of non-metallic pipes is supported with market trends towards higher pressure rating and higher temperature resistance pipes to meet stringent downhole well requirements. System challenges, load cases, testing requirement, financial aspect based on well construction and downhole condition are described in depth, focusing on a viable pathway to implement non-metallic tubulars in different wells throughout the lifecycle phases in different applications from water injection to oil and gas production.
This study identified the lacking aspects of a fundamental ecosystem needed to confidently deploy non-metallic pipes downhole. By addressing the R&D work necessary for the industry to focus on, efforts can be guided to fill in the missing gaps to build a fundamental ecosystem in order to replace steel tubulars gradually for desired properties. Depending on application requirement, selected non-metallic pipes are designed with various constraints and practical considerations which eventually needs to be tested and qualified for application in demanding well conditions (e.g. wet high temperature and pressure).
Other factors than pipe design play as integral component such as connection design and compatibility with existing casing and tubing accessories requires parallel development. Compatibility of connection, end-fittings, and supporting well accessories including drilling tools, completion packers, tubing and casing hangers requires thorough compatibility assurance. Logging tools, etc. are to be either delicately planned out or even require parallel development to accommodate the alternative pathway in place of traditional practices. Detailed study on how non-metallic tubular react to conventional drilling, completion and intervention activities is fundamental to ensure system integrity throughout the well construction process and well lifetime. Emphasis is placed on gap analysis of downhole infrastructure system and associated challenges to utilize non-metallic tubulars and related compatible components in drilling, completion, logging, intervention, and production conditions, as well as the lack of qualification standards for downhole non-metallic tubulars.
Integrating the Fully Coupled Geomechanical with Thermodynamics Modeling for Accurate Pore Pressure Prediction - A Case Study from China
Authors: Li Wei , Xing Yangyi , Qin Xu , Chen Weiming , Jiang Lin , Luo Tongtong , Xu Hanbing 
Published: October 2022

Abstract
The accurate prediction of pore pressure relates directly to various important affects oil and gas field exploration and development including drilling engineering design and formulation of oil and gas reservoir development plans. The well logging information with unique advantages such as high vertical resolution and capability of continuous measurement has been widely used in formation pore pressure prediction. Currently, though the industry has developed many methods for formation pore pressure well logging prediction, they may not be all used to calculate formation pore pressure in actual production. And it may be difficult to guarantee the prediction accuracy with a single method. In order to accurately predict formation pore pressure, this paper systematically reviewed domestic and foreign literatures on formation pore pressure well logging prediction, explained the methods and principles of each prediction technique in detail, and summarized the applicability of each formation pore pressure prediction technique in detail. This paper concluded that both the effective stress method and the Bowers method could be used to accurately predict the formation pore pressure, and the empirical statistical model method also had high prediction accuracy, while the equivalent depth method and the Eaton method which are subject to the accuracy of the normal compaction trend equation had relatively poor prediction effect. It will be a trend in this field to construct the formation pore pressure nonlinear prediction model based on mechanical parameter tests in the study area with organically integrating geophysical well logging and pressure detection data. The study area is located southwestern China, the deep formations that more than 4000 meters are high temperature (150-180 deg C). Thermal-related secondary pore pressure generating mechanism may become active leading to higher overpressure and difficulties in prediction. For the case study, an empirical relationship of overpressure impact factors versus temperature of shale was proposed. An accurate pore pressure model generated using available well-scale geomechanical model and overpressure impact factors. With an integrating fully coupled PPP model as foundation, the integrated approach helps deep wells to reduce serious wellbore instability caused by abnormal formation pressure, wellbore collapse and other complex drilling problems.
A Business-Oriented Feature Selection Method for Enhancing Machine Learning Based Digital Tools Adoption in the Energy Industry
Authors: Corneo Andrea , Suardi Mauro , Lancia Lorenzo , Cannarile Francesco , Fidanzi Alessandra 
Published: October 2022

Abstract

Objectives/Scope
To ensure that predictive models based on Machine Learning (ML) techniques can be fully exploited by energy plant operators, these should be trained on "actionable" features, i.e., a set of features that are explainable and on which operators can directly act to take mitigative and/or preventive actions. To this aim, we have developed a business-oriented feature selection approach which identifies actionable features while optimizing the model predictive capability at the same time.

Methods, Procedures, Process
We have developed a solution which frames the feature selection step as a Multi-Objective Optimization (MOO) problem which relies on genetic algorithms as search engine. The MOO returns a set of optimal feature subsets referred to as Pareto optimal front on which the best compromise solution in terms of model performance and ‘actionability’ must be chosen. For selecting an optimal solution from the Pareto optimal front, the TOPSIS method has been embraced which automatically ranks the candidate solutions based on their relative importance that the users assign to the two objectives to be optimized.

Results, Observations, Conclusions
The proposed methodology has been successfully applied to a real case study concerning cracking furnaces of a petrochemical plant. The optimized predictive model resulting from the application of the developed feature selection strategy has shown to be properly suited for plant operators allowing them to easily derive insights and properly take actions based on the model output. Further, due to the agnostic nature of the proposed methodology, this can be easily extended and applied to other Energy case studies where "actionability" is a driving key for the successful adoption of digital tools based on ML models.

Novel/Additive Information
To the best of Authors knowledge, the proposed approach which embeds the "actionability" property of a feature as criterium in the feature selection step and automates the process of selecting an optimal solution through the TOPSIS method, is novel from a methodological point of view in the field of machine learning applied to energy transition use cases.