bluuebunny/crossref_metadata_2025_split huggingface dataset:
Unlocking the Downthrown Potential of Mature Brown Fields, A Success Story from Amal Field, Gulf of Suez Rift, Egypt
Authors: Okeil Mohamed , Abd El-Moniem Mohamed A. , Abd El-Maboud Mohamed , Osman Heidar , Abd El-Rahman Raafat , Keshta Emad , Khafagy Abd El-Nasser 
Published: May 2024

Abstract
The Gulf of Suez rift basin continues to unveil its secrets with each new discovery. Among these discoveries, the Amal field, with more than thirty years of production, stands out as a significant brown mature field that recently revealed a downthrown oil discovery of a prolific structure trend (B-trend fault) in the offshore southern province. While this discovery bears some resemblance to other analogues of proven downthrown fields, it holds a unique distinction. Specifically, the oil-water contact in this discovery is located even deeper than the up-thrown contact in the main field by over 200 meters within the same reservoir. Moreover, it is deeper than the deepest recorded oil-water contact in the main field by 80 meters, a phenomenon not previously observed in similar downthrown traps.
This paper provides a comprehensive workflow that has been integrated prior to this discovery, highlighting the associated risks. The paper also addresses the challenges regarding the poor seismic data quality that hinders the better subsurface reservoir structure image and explains how the integration of all available data has helped to overcome this limitation. Despite being a remarkable success story, the drilling results revealed valuable lessons learned and unexpected risks that should also be considered in future prospect evaluations.
This remarkable discovery encourages additional near-field exploration in other mature brownfield locations across the entire Gulf of Suez rift, as it demonstrates the hydrocarbon potential within downthrown traps. Additionally, the discovery has the potential to reshape exploration strategies, particularly to the significant bounding faults that encompass extensive undrilled regions within development leases.
Impact of Spacer Structure on Organic Acids Desorption Efficiency Induced by Gemini Surfactants
Authors: Deng X. , Kamal M. S. , Patil S. , Shakil S. M. , Shalabi E. A. , Hassan A. 
Published: May 2024

Abstract
Organic acids, together with other polar molecules, constitute the oil-wetting components in crude oil. A commonly adopted understanding is that the adsorption of organic acids leads to the further adsorption of organic materials on the hydrophobic tail groups of the adsorbed organic acid molecules, making the rock surface oil-wet. Although the impact of organic acids in oil-wetting of the rock surface has been unfolded for many different conditions, there are still some questions around the oil-wetting reactions induced by organic acids. A group of in-house synthesized cationic gemini surfactants have been shown effective in altering rock wettability from oil-wet to water-wet conditions. To study the impact of spacer structure on organic acids desorption, experiments were taken to show the impact of the water film in the oil-wetting process of rock by organic acids, and the effectiveness of different cationic gemini surfactants in wettability alteration. SEM and zeta potential experiments were conducted to show the adsorption and desorption of organic acids. Static contact angle measurements were conducted to show the wettability change. Difference in the wettability alteration performance was closely related with the spacer structure. Results showed that polarity of the spacer group is not the only factor that impacts the surfactant's potential in changing rock wettability.
4D Ultrasonic Caliper While Drilling Enables Advanced Wellbore Evaluation in Slim Hole Size
Authors: Fouda M. , Taher A. , Soelem R. 
Published: May 2024

Abstract
Evaluation of hole conditions is a key measurement for safe drilling and completion operations. Acquiring an accurate hole size measurement has been traditionally performed using wireline mechanical calipers deployed after drilling operations have been completed. This paper demonstrates how logging-while-drilling (LWD) ultrasonic sensors can be used to provide a time-lapse (4D) alternative azimuthal measurement of hole size, enabling data acquisition in different phases of drilling and tripping operations.
LWD ultrasonic caliper measures the travel time and computes the tool’s stand-off to the wellbore wall. Acquiring azimuthal data around the wellbore during different logging passes enables acquisition of 4D caliper information. After being calibrated inside casing, the ultrasonic sensor provides azimuthal travel-time images, based on which minimum, maximum, and average hole sizes can be computed.
Data have been acquired in drilling, trip-in, and trip-out modes and compared to wireline-oriented calipers. The data has been evaluated considering time-dependent deterioration, washout, and breakout developments.
Recently introduced LWD slim ultrasonic imaging and caliper tools have multiple transducers and fast sampling rates. The hardware and algorithm design improves the hole size computation and wellbore evaluation. The tools provide a viable alternative to wireline mechanical calipers. While field data showed a good match in competent formations, differences between data acquired in multiple LWD logging passes and wireline mechanical caliper runs have provided 4D caliper information for evaluating time-dependent changes in hole conditions enabling future optimization of well construction.
This paper illustrates the utilization of LWD ultrasonic sensors integrated as part of the drilling assembly to provide a 4D azimuthal measurement of hole size at different times, during drilling and tripping in and out of the hole.
A Machine Learning Based Framework for Brine-Gas Interfacial Tension Prediction: Implications for H2, CH4 and CO2 Geo-Storage
Authors: Pan Bin , Song Tianru , Yin Xia , Jiang Yiran , Yue Ming , Hoteit Hussein , Mahani Hassan , Iglauer Stefan 
Published: May 2024

Abstract
Brine-gas interfacial tension (γ) is an important parameter to determine fluid dynamics, trapping and distributions at pore-scale, thus influencing gas (H2, CH4 and CO2) geo-storage (GGS) capacity and security at reservoir-scale. However, γ is a complex function of pressure, temperature, ionic strength, gas type and mole fraction, thus time-consuming to measure experimentally and challenging to predict theoretically. Therefore herein, a genetic algorithm-based automatic machine learning and symbolic regression (GA-AutoML-SR) framework was developed to predict γ systematically under GGS conditions. In addition, the sensitivity of γ to all influencing factors was analyzed. The prediction results have shown that: the GA-AutoML-SR model prediction accuracy was high with the coefficient of determination (R2) of 0.994 and 0.978 for the training and testing sets, respectively;a quantitative mathematical correlation was derived as a function of pressure, temperature, ionic strength, gas type and mole fraction, withR2= 0.72;the most dominant influencing factor for γ was identified as pressure.
These insights will promote the energy transition, balance energy supply-demand and reduce carbon emissions.
Gas Rate Predictive Model as an Alternative to Choke Equations
Authors: BinZiad Abdullah , Khan Abdul Muqtadir , Alshammari Fahad O. , Alsubaii Abdullah 
Published: May 2024

Abstract
Choke equations are usually developed for specific conditions, calibrated, and validated with separator data. There is a vast opportunity for data model deployment in this space, which can enhance the accuracy of gas rate predictions further. In this work, a data model approach uses machine learning (ML) techniques to predict gas rate for a given set of measured inputs.
A structured, relational dataset was created from 1,181 wells where full separator setup was utilized. A total of 18 variables such as choke size, flowing wellhead pressure, fluid flow rates, gas-liquid ratios, and PVT properties were captured and subjected to data cleaning, feature engineering with correlation matrices, feature scaling, and other techniques to reduce the number to 11 important variables. A comprehensive ML workflow was utilized with exploratory data analysis using a 65:35 set split for training and holdout sets with a fivefold cross validation and considering feature importance, utilizing seven regression algorithms and a neural net.
Exploratory data analysis led to some data cleaning based on missing values and data QC, leaving data from 448 wells. This final dataset was then subjected to cross validation and hyperparameter tuning. Several algorithms were compared utilizing the performance metrics such as root mean squared error (RMSE), average absolute percentage error (AAPE), mean absolute percentage error (MAPE), and R-squared (R2). The XGBoost model performed the best with the AAPE and MAPE of 1.9%, MSE of 0.04, and R2 of 0.996. As a result, an application based on the XGBoost model was developed to improve the gas rate accuracy during flowback operations. Feature importance was also studied and showed that total condensate volume and condensate gas ratio were the most important predictors. In comparison with the traditional and modified Gilbert choke equation, with an average error of ~5 to 8%, and RMSE of ~14, the error with this ML approach is a few folds lower because the data approach captures and handles the variance better. In addition, the choke equations yield much higher errors in eccentric conditions of low gas rates and high water condensate ratios. The error comparison with a few different analytical models is presented here and shows that the XGBoost performed better than the existing models. To simplify the computational time and resources, an attempt to map the XGBoost output into a simple linear equation is also presented, along with its accuracy.
Data-based approaches provide a high level of operational and cost relief in the surface well testing domain, but this space has not been well explored. This work shows the value and benefits of the ML models in well testing domain.
Innovative 15K Cemented Multi-Stage Fracturing Technology- Minimizing Deployment Risks and Enhancing Time Efficiency in Complex Horizontal Wells
Authors: Agarwal Rohit , Essmat Nooruldeen Zeyad , Levario Jesus , Bansal Sarvodaya , Corona Mauricio , Alismail Ahmed , Almuallim Mustafa , Paz Daniel 
Published: May 2024

Abstract
Deployment of Open Hole Multistage Fracturing (OH MSF) completion system in long horizontal wells has always been a daunting task, and often presents high risk of getting stuck in open hole due to complex completion design with very stiff assemblies that include multiple large OD - hydraulic set open hole packers. This paper introduces a novel technology called Cemented MSF, which addresses the deployment risks associated with conventional OH MSF and cemented liner. Notably, this technology eliminates the need for time-consuming coil tubing operations for plug-and-perf (in cemented liner), thereby avoiding production delays.
The paper examines the major bottleneck in deployment of OH MSF, a very stiff completion string, which is particularly influenced by the number of stages/ open hole packers, elevating the risk of equipment getting stuck in the open hole due to ledges and washout created while drilling the reservoir. Consequently, there is a constant trade-off between maximizing deployment chances and minimizing the risk of getting stuck by reducing the number of stages. However, this trade-off comes at the expense of production efficiency.
Cemented MSF is a hybrid integrated system that provides all the production benefits of OH MSF with significantly reduced deployment risk. In this novel solution, OH packers are eliminated, and the completion is run in a similar process like a cemented liner. The cemented MSF lower completions were successfully implemented in a long horizontal well with &gt; 6,000 ft of reservoir contact. While drilling the lateral section, this system enables greater degree of directional flexibility and navigation control as compared to conventional OH MSFs, which have very strict limitations for dogleg and inclination citing risk of deployment complexities with the stiff completions string. Having no OH packers eliminate the need to record open hole logs for packer's placement and further eliminates the need for a simulation run (Dummy Run) to simulate actual completion string stiffness, resulting in a direct savings of minimum six-days. Furthermore, to ensure that the frac ports are not activated prematurely, a fit for purpose cementing program was developed using precise volume and hydraulic displacement calculations and optimum shoe track length. Among the unique features of this system is its ability to run maximum possible stages, ensuring that productions will not be compromised. At the end of completion phase, the frac Ports can be activated by dropping balls just like a conventional OH MSF system and get the well for production.
The paper outlines essential design considerations, checkpoints, an execution phase roadmap, and potential contingencies related to the deployment of the Cemented MSF technology.
The Road to Enhanced Quality: Lessons from a Company's Transition to APIQ2 From ISO9001:2015
Authors: Akram A. , Yahya A. , Affandi B. 
Published: May 2024

ABSTRACT
This paper describes the pivotal journey of a local upstream service provider in transitioning its Quality Management System (QMS) from ISO 9001:2015 to API Q2:2021, with a specific focus on the upstream services sector within the petroleum industry. The primary objective of this transition was to align the company's QMS with international service standards, thereby enhancing its global competitiveness and service quality. This study offers a comprehensive examination of the strategic approaches employed, the inherent challenges confronted, and the significant benefits realized through this transition.
Initially, our methodology entailed a thorough benchmarking of the existing QMS against the standards set by leading international service providers in the petroleum sector. This process involved a detailed gap analysis between the ISO 9001:2015 and API Q2:2021 standards to identify critical areas for improvement. The transition strategy was meticulously structured, encompassing comprehensive staff recruitment and training, process optimization, and rigorous internal audits. A key aspect of our approach was the active engagement with subject matter experts and stakeholders, ensuring our practices were in strict alignment with international standards. The implementation of this transition was executed through a series of iterative enhancements in our service delivery processes, with a relentless focus on aligning with the superior service quality norms of leading international players.
The results from this transition were profoundly positive. We observed a 35% increase in compliance with global quality standards, coupled with an enhancement in customer satisfaction ratings. These improvements underscore the robust focus of API Q2:2021 on service quality and risk management, essential for matching international standards. The transition not only elevated the service quality of our local operations but also improved our global competitive position and recognition in the international market. Furthermore, the process instilled a culture of continuous improvement and operational excellence among our staff.
While ISO 9001:2015 lays a foundational framework for quality management, the adoption of API Q2:2021 is instrumental for local service providers in the petroleum industry to not only meet but exceed international service standards. This transition is pivotal in enhancing service quality and strategically positioning local service providers on the global map. Our study contributes significantly to the existing body of knowledge, providing a practical blueprint for similar organizations aspiring to elevate their service standards to meet international benchmarks in the petroleum industry.
Aligning Upstream Operations with Sustainable Technology: High Power Lasers
Authors: Alghamdi S. , Batarseh S. , Alharith A. , San Roman Alerigi D. P. , Alrashed A. A. 
Published: May 2024

Abstract
The application of practical sustainability and safety principles in a perforation job is pivotal to safeguard not only the environment and workers’ well-being but also, the long-term viability of resource extraction. In light of the first industrial high-power laser perforation, the objective of this work is to explore the sustainability and safety aspects of laser perforation with a focus on factors such as water requirement, asset integrity, logistics, safety and surface footprint.
This work examines the operational conditions of conventional stimulation methods and the first industrial successful deployment of high laser perforation tool in the field with a focus on safety, logistics, environmental impact, surface footprint and technology efficiency. Furthermore, the paper presents the effect on well integrity after the perforation process with a laser tool including debris management, steel integrity, effect on the formation properties, quality of perforation tunnels. Experimental data obtained from photomicrographs, acoustic testing, and imaging were used for validation and analysis.
The design of the laser system deployed is enclosed with small surface footprint. It comprises a laser energy generator, nitrogen tank, coiled tubing unit, and the tool. The laser tool eliminates the use of explosives, such as shaped charges, promoting safety and eliminating the extensive logistics of handling explosives in the wellbore. The laser tool can perform as many perforations as required in a single trip reducing rig time efficiently. This technology provides versatility to suit the wellbore specification in terms of size, shape, and depth of perforation, promoting efficient completion of wells. After perforation, photomicrographs and acoustic testing proved that the use of high-power laser does not compromise the integrity of steel, maintaining the existing asset integrity. Furthermore, the precise control over the phase of the rock maintained the perforation tunnel and formation integrity. The non-explosive effect of laser perforation eliminates compaction around perforation tunnels abolishing post-stimulation formation damage, which provides long-term viability of resource extraction. The waterless, rigless, and non-explosive, features of the laser perforation technology align seamlessly with the International Petroleum Industry Environmental Conservation Association's (ipieca) roadmap to achieve the United Nations Sustainable Development Goals (SDGs) in the oil & gas industry.
High power laser is an innovative breakthrough technology that will revolutionize the industry, this paper demonstrated the potential of the technology and its alignment with the recommended sustainability and safety practices. High power laser tool is a multifunctional tool that can provide different applications with the same power source and tool.
Perf, Wash and Bismuth : First in the World Innovative Technology - Implementation for Gas Leak Isolation in Plug and Abandonment (P&A)
Authors: Hamid A. Abdul , Razak M. N. Abdul , Zawawi A. , Shah S. Masroll , Khalid M. I. , Ezani F. S. , Kumar A. Kishore , Sellapan S. 
Published: May 2024

Abstract
A gas leak incident, from the Casing Annulus of a well, reported in Malaysia Platform. This event involved the release of a gas cloud from the well and surfacing of water and mud through the surface casing. It necessitated an immediate evacuation. In response, the decision was made to plan for the P&A of the well, resulting in temporary production halts and the suspension of nearby drilling operations. This had financial repercussions for the company. In light of the intricate nature of P&A, the team conducted an evaluation and introduced a ground breaking technology, "Perf, Wash, and Bismuth," which is the first of its kind in the world. This technology was implemented to create a robust well barrier, ensuring the well's security and preventing leaks in both the well and its annulus.
A custom tool was meticulously designed to align with the well's plugging and abandonment (P&A) process, involving extensive technical consultations and problem-solving sessions before the Bismuth's fabrication. This technology's application in the context of an HWU Rig setup introduced various limitations and challenges, including restricted crane capacity and deck space. To address communication within the casing annulus, the team creatively adapted the traditional Bismuth application, implementing the "Perf, Wash, and Bismuth" technique to create a secure seal behind the casing, ensuring a Casing Pressure reading of 0 psi. Before placing the Bismuth Plug, the leak point was identified, and a Perforation Gun and Wash tool were employed to perforate and cleanse at the specified depth. Bismuth activation relied on a time-based mechanism, with three separate Bismuth plugs, each about one meter in length, installed. This comprehensive Bismuth plug operation, from setting to retrieval, Run In Hole, setting, and tagging, took roughly 18 hours.
Three Bismuth plugs were successfully set and tagged on the well. Each plug was tagged to determine its top, and this information confirmed that the Bismuth had entered the annulus through the pre-perforated channel, demonstrating the effective deployment of the Bismuth Plug using the HWU rig when proper planning was in place. After placing the Bismuth plug, the absence of pressure within the annulus indicated the well was secured. This newfound confidence in the well status enabled the platform to resume production and come back online.
The "Perf, Wash & Bismuth" Innovative Technology, a ground breaking world-first, provides a solution for addressing complex P&A wells with annulus casing leaks. This paper outlines the utilization of bismuth in P&A wells, its deployment through the HWU Rig, the associated engineering and installation procedures, and offers a comprehensive overview of its implementation. It also hints at the future potential of this technology in the realm of P&A wells.
4D Seismic Inversion of Quality Factor and Velocity
Authors: Chen Jianming , Zhao Yansheng 
Published: May 2024

Abstract
Rock properties play a crucial role in influencing the propagation of seismic waves within the Earth, providing valuable insights into various aspects such as the presence of hydrocarbons, porosity, saturation, and permeability variations. Seismic imaging serves two main purposes: mapping the heterogeneity of underground reservoirs and monitoring recovery processes on-site (Nur, 1989). Over time, both production and injection activities alter the response of the reservoir. Time-lapse (or 4-D) seismic monitoring is an essential tool for reservoir management, enabling the tracking of displacement processes. Changes in seismic properties, such as velocity and quality factor Q, can offer quantitative estimates of fluid changes.
Some rock properties related to fluid saturation in the reservoir, such as anelastic absorption quantified by the quality factor Q, can undergo more significant changes than others, such as oil and gas mixed with brine or CO2. To estimate the quality factor Q from seismic reflections, a tomographic inversion algorithm is utilized based on the frequency shift method (Quan and Harris, 1997). This algorithm generates a macro-model for anelastic attenuation. In order to enhance resolution and obtain a micro-model, Poggiagliolmi and Vesnaver (2014) propose a new algorithm that is stable and reliable for computing the instantaneous frequency, which represents the centroid of the instantaneous spectrum. This algorithm improves the stability of calculating the instantaneous frequency and provides a high-resolution image of anelastic absorption. By utilizing this approach, the resulting broadband image of anelastic absorption in depth can offer superior monitoring of reservoir changes compared to conventional methods.