bluuebunny/crossref_metadata_2025_split huggingface dataset:
Seismic Reprocessing Leads to New Breakthroughs——A Successful Case in the ASH Field, A.G. Basin in Egypt
Authors: Elokr Mohamed , Lotfy Ahmed , Xing Wei , Li Huijing , El Bassioni Ahmed , Moatasem Nader 
Published: March 2023

AbstractASH oil field located in the east of the AG Basin in Egypt. Lower Cretaceous Alam El Bueib is the main oil producing formation. Due high heterogeneity of the Abu Roash Members succession in addition to the influence of thick limestone of the Upper Cretaceous and the influence of multiple complex faults, the quality of seismic data is very poor. This is mainly manifested in, a, the variation of vertical velocity in lithology changes resulting a significant error in depth migration; b, the fault imaging is not clear due to low S/N ratio, which leads to serious challenge for structure mapping. Therefore, the seismic re-processing was carried out.Two key techniques were carried out to achieve the target, that: uses new well VSP data to adjust the velocity model and CRAM PSDM for re-processing.Adjusting the velocity model: The previous PSDM acquired in 2015 had no well control covering the deeper target of Alam El Bueib Formation but the advantage of using VSP data of ASH-3 well as a well control for building new velocity model of the reprocessed data. CRAM PSDM re-processing: The CRAM (Common Reflection Angle Migration) is a cluster-based imaging system that generates conventional reflection angle gathers without azimuth dependency. Optimal local tapered beams are internally created and imaged to form high-quality image gathers, which can then be used in standard interpretation systems for accurate velocity model building and amplitude inversion (AVA).Applying CRAM technology in depth migration instead of Kirchhoff depth migration, has a great impact on enhance the final seismic image. The CRAM algorithm is using the Ray path migration of the seismic signal instead of using migration aperture as in Kirchhoff. Applying the ray path migration helps in adopting the seismic trace position ultimately enhance the fault definition and S/N ratio at the deeper target levels.As a practical case from the comparable seismic sections, same arbitrary line in different seismic volumes, the reprocessed data showed a high level of improvement in fault definition specially in the north portion of ASH field closer to the major fault which was very poor in the previous data. In the reprocessed CRAM PSDM data, the good amplitude extended towards the north and west portions of the field, which allowed to define the faults through Alam El Bueib horizon and decrease the uncertainty of the new proposed well location in the entire field. (Figure 1)Figure 1 Amplitude comparison between reprocessed and original data, ASH field
Cloud-Based Software for Automated Well Planning
Authors: Hassan Mohamed Ali , Strand Jim , Remmen Per Inge 
Published: March 2023

AbstractThe Automatic Well Design workflow presented in this paper is a starting step to achieve Well Construction Autonomy. This workflow made possible through modern "API" based drilling calculation engines hosted on a cloud computing environment.In the Drilling Digitalization Infrastructure, everything will be connected via Open APIs, and Real time Machine-to- Machine Communication. Modern Cloud-Based Applications will enable Engineers, within seconds, to automatically execute complex drilling simulations and calculationsThis software tool, named WellDesign, is a cloud based single page application utilizing networks and cloud computers for data storage and collaboration. It offers a set of application programming interfaces (API), enabling machine-to-machine communication & 100% automation, where whole or parts of the software can be operated by other computers. On top of this interface, the software tool has a 2D and 3D human graphical user interface, utilizing web technologies such as accelerated 2D (Canvas, 3D.js) and 3D (WebGL, three.js) graphics. This software tool aims to run on all kinds of computers (Windows, Macs) and other interactive devices supporting modern web browsers (tablets, phones and similar).Well Construction Automation is gradually becoming more prominent in oil & gas industry. It encompasses the application of digital technology in all aspects of well drilling and completion (i.e., automatic well design, digitalization of downhole tools & surface equipment, remote monitoring, real time data transmission, and robotic rig systems).In today's Industry 4.0 transformation world, easy-to-use cloud-based software can partially automate Oil & Gas wells design. Future software development should be made to produce fully autonomous Oil & Gas well designs while maintaining industry safety & well integrity standardsThe Automatic Well Design workflow presented in this paper is a starting step to achieve Well Construction Autonomy. This workflow made possible through modern "API" based drilling calculation engines hosted on a cloud computing environment. In the Drilling Digitalization Infrastructure, everything will be connected via Open APIs, and Real time Machine-to- Machine Communication.Modern Cloud-Based Applications will enable Engineers, within seconds, to automatically execute complex drilling simulations and calculationsTwo automatic design workflows shall be illustrated in detail:Automatic Well Trajectories Automatic Casing Design
Developing Local Talent from the Concession Area at United Energy Pakistan
Authors: Nizamani Abdul Bari 
Published: March 2023

Abstract
Objective/Scope: The purpose of this paper is to study how UEP has implemented Field Production and Maintenance Trainee Programs. It will further evaluate the effectiveness of the program and how it has benefited the local community and the company.
Methods, Procedures, Process: UEP's Field Trainee program provides opportunities for young people from the concession in which UEP operates. It creates jobs for local youth to get trained and work in the oil and gas sector.
The process to recruit the local and train them is extremely rigorous. The applications are invited via placing an advertisement in the local newspapers. Candidates meeting the criteria, undergo a rigorous test and interview process. Candidates shortlisted on merit are selected. The training of selected local high school graduates is initially performed in the classroom by senior faculty of renowned local Sindh university. After completing classroom training, they embark on an on-the-job training plan under the supervision of seasoned industry professionals.
Results, Observations, Conclusion: Over many decades the UEP trainee program has developed skillset of the locals and has given them employment opportunity. It has provided a talent pipeline for the organization and helped UEP give back to the community as part of its commitment. Several senior positions at UEP are occupied by employees inducted through this program. Some of them are working for other multinational organizations in Pakistan and abroad. Apart from developing the talent pool, this program has increased organization's brand value especially amongst the locals and has helped the organization forge meaningful relationship with the local community.
Novel/Additive Information: This program has been a great success story for UEP. It shows that benefits are not limited to meeting the workforce requirement. Other organizations in Pakistan and abroad can learn from UEP's success and may introduce similar programs. This program is mainly focused on hiring resources for Operations functions. Going forward, the need for introducing similar program for other functions can be evaluated.
Late Time Response Analysis in Pressure Build Up Tests: Challenges and Solutions
Authors: Motaei Eghbal , Ali Anwar Husen Akbar , Rozali M Irsyad B 
Published: March 2023

AbstractOne of the most important features that impacts the facility size and production rate commitment is the minimum connected volume which can be explored through pressure Build Up and any misinterpretation, costs the operators significantly. This paper aims to address the challenges in Late Time Response analysis of pressure Build up well tests that exploits the reservoir boundary. Knowing that the well test response at late time shows the fingerprint of multiple features such as aquifer, sand discontinuity, baffles, faults, boundaries, etc., it will be challenging to quantify the extends of the reservoir using convolved late response.Two main numerical models were built for oil and gas reservoirs in an elongated reservoir to study the lateral boundary features such as closed boundary and aquifer and understand the effect of these features on late time response to get a clearer response. Using two models, the impact of mobility contrast between the hydrocarbon, boundary distance, aquifer strength, boundary movement and structure complexity was simulated.The major finding of this paper is that a unit slope straight line can be seen in buildup test which doesn't fit any classical and analytical model for pressure build up as the expectation is to have negative slope and down-ward hump for build up response of closed boundary and aquifer. However, this can be explained through mobility reduction from hydrocarbon (oil/gas) to water. The simulation time (build up test duration) was extended to see the long-term impact theoretically and at the end the same expectation was confirmed by simulation. After radial flow, channel flow (half slope) and then unit slope (mobility reduction) and then at last the drop in the derivative response is observed. However, the drop as signature of aquifer or limited volume happened beyond practical test duration (&gt; 1000 hours).The work highlights the true workflow to identify the true response from reservoir and have reliable reservoir characterization and shows the case studies that address the cost on 1) misinterpretation of late time response and 2) excluding the well test from analysis due to its complexity to highlight the value and criticality of the integrated analysis.
Investigation of Hydraulic Fracturing Sensitivity to Water Injection Volumes In Wolfcamp Formation
Authors: Saeed Yousef Tareq , Alhajeri Mubarak Muhammad , Barati Ghahfarokhi Reza 
Published: March 2023

AbstractHydraulic fracturing is a common stimulation technique in oil and gas production to stimulate wells with low permeability. An optimum fracture half-length is designed by injecting the right amount of fracturing fluid to achieve successful results. Otherwise, injecting lower than the optimal amount will cause a poor fracture network, water blockage, and phase trapping of oil and gas behind the fracture space while over injection may result in frac hits and unfavorable economics. This paper presents the importance of the optimum fracture half-length and the role of injection volumes to generate such a length. CMG models were created to study the correlation of different parameters during hydraulic fracturing in the Wolfcamp formation (Permian basin): fracture permeability, water saturation, and capillary pressure. Three CMG models with different fracture half-lengths of 100ft, 200ft, and 350 ft were created. Sensitivity analysis of facture permeability was performed on each model using different values, e.g. 0.1, 1, 10, and 100 md. Representative cases were selected based on the sensitivity analysis results on fracture permeability. Fracture permeability was then changed in each model and was 5 md for the first model, 10 md, and 20 md for the second and third models, respectively. The effect of water saturation was also studied by changing the water saturation from 45% to 55% in an increment of 5% in each simulated model. Finally, the capillary pressure data was added to each model to study the effect of water blockage. Economic analysis was studied to determine the best-case scenario in terms of higher NPVs and RORs. Sensitivity analysis of facture permeability indicated that as fracture permeability increases, then an increase in hydrocarbon production is achieved in which the water saturation was the conclusive parameter. For instance, hydrocarbon production rates were the lowest in the first model which had the lowest fracture half-length and, therefore; fewer water volumes were injected. The second model with a fracture half-length of 200ft as the optimum length provided the optimal amount of injected water and gave the highest amount of incremental Hydrocarbon production, i.e. water saturation and fracture permeability were higher than the previous one. The last model, which has the highest fracture half-length and also the highest amount of injected water showed a significant amount of formation damage. A higher amount of injected fluids caused a high capillary pressure that was responsible for blocking the fractures and caused a decrease in relative permeabilities. The amount of injected water during hydraulic fracturing will significantly affect oil and gas production. CMG models, decline curve analysis, and economic studies showed that designing the optimum amount of injection volumes is key to a successful hydraulic fracturing treatment and minimizing the risk of causing any damage to the formation.
Physical and Numerical Simulations of Offset Well Pair Combined Steam Drive and Gravity Drainage Process to Develop Super-Heavy Oil or Oil Sands Project
Authors: Liang Guangyue , Xie Qian , Liu Yang , Liu Shangqi , Xia Zhaohui , Bao Yu , Zhou Jiuning 
Published: March 2023

AbstractSteam assisted gravity drainage (SAGD) using parallel dual-horizontal wells made great success in developing heavy oil or oil sands projects. However, the performance may be greatly impaired when shale laminae with high frequency exist. In order to enhance oil production and decrease steam to oil ratio (SOR), this paper conducts feasibility study of offset well pair using steam drive and gravity drainage to develop oil sands project by overcoming shale laminae.Physical simulations of offset well pairs under three horizontal distance were first carried out to analyze the mechanism. On the basis, homogeneous model and heterogeneous model incorporating staggered shale laminae were constructed, respectively. Then numerical simulations of conventional SAGD well pair and offset well pair using steam drive and gravity drainage were conducted to evaluate the influence of pay thickness and possibility of mitigating adverse impact of shale laminae. Moreover, several configurations of offset well pairs and their application results were proposed.The results of physical simulations indicate that there is larger lateral steam chamber development compared with conventional well pair. While for numerical simulations, for homogeneous case, compared with conventional well pair, offset well pair achieves similar performance but delaying oil production for 0.5 year, and the performance cannot be improved significantly even if aggressive pressure difference or subcool control is enforced. But for heterogeneous model with existing inter-well shale laminae, offset well pair can significantly improve early to mid-term performance and accelerate early steam chamber growth by enforcing pressure difference. But once steam chamber has grown to a certain height, there is no big difference between offset and conventional well pairs. Furthermore, three configurations of offset well pairs are evaluated including the injector drilled 3 m high and 4 m laterally from the producer, offset horizontal injector and multilateral producer, and multi-stage hydraulic fracturing or dilation assisted enlarge well spacing of 10-30m. Encouragingly, offset horizontal injector and multilateral producer has made great success by a combination of steam drive and gravity drainage in Canadian Surmont oil sands project.The proposed technology was first studied by combined physical and numerical simulations, and it can be effectively applied to relatively low quality oil sands projects such as thin pay and challenging pay with staggered shale laminae. Several configurations of offset well pairs have been listed as pilot suggestions.
A Novel Technique for the Quantitative Determination of Wettability of a Severely Heterogeneous Tight Carbonate Reservoir
Authors: Al-Sayegh Saleh , Flori Ralph , Al-Bazzaz Waleed , Abbas Abdulaziz , Qubian Ali , Al-Saedi Hasan 
Published: March 2023

AbstractThe objective of this study is to accurately measure the wettability contact angle of a cretaceous carbonate reservoir in a vertical well set-up known for as an unconventional tight carbonate oil reservoir. Also, to investigate the relative heterogeneity of these samples using digitally captured images; these images accurately capture natural pore-system in this carbonate rock samples and their wettability performance attributed towards building a vertical depth wettability/ heterogeneity model. To capture, measure and model natural tight matrix static contact angle wettability in order to understand their new physics that will advance unconventional tight oil reservoir characterization.Entire vertical well depth reservoir core rock samples, in the form of rock fragments, are selected, then imaged, and then characterized for porosity, permeability, tortuosity/ heterogeneity, and pore/ grain-wettability contact angle in 2D format utilizing SEM-BSE imaging techniques. The generated big data images will be quantified using pre-defined logic for tortuosity/ heterogeneity and wettability contact angle measurement. Each rock sample will process several images captured at X40 (mm), X400 (μm), and X4000 (nm) magnifications and will investigate wettability/ heterogeneity relationships for unconventional tight pore system from the entire vertical depth.From measured data and computed logics, the major portions of captured rock investigated show water wet tendency. The wettability distribution in the vertical 250 feet shows strong to medium and even weak water-wet system variation (θ = 10° - θ = 90°). The dominant wettability is medium-water-wet (θ = 30° - θ = 60°), and it is found in the middle section of the vertical column. Medium-water-wet indicates a good candidate for secondary recovery water injection development programs. This study includes tortuosity/ heterogeneity quantifications from imaging 2D technology which is valuable in understanding vertical/ horizontal fluid movements.The authors feel that this study will narrow the gap in understanding contact angle wettability, heterogeneity characterizations from static conditions viewpoint and hence, the reservoir crude oil recovery vertical profile history from vertical rock samples.
Intelligent Course Recommender for Professional Development
Authors: Al Mudaifer Danah Adel , Al Qahtani Rahaf Salem , Veettil Tharayil Sarafudheen , Almass Abdulaziz , Dursun Serkan 
Published: March 2023

AbstractOne of the major challenges faced in oil and gas industry today is talent management of its workforce. Training the workforce and suggesting the right training courses to the individuals is important in talent management and career development. There are many training recommendation systems available using different machine learning approaches such as collaborative filtering, neural networks and hybrid models. In this paper, an intelligent recommendation system is proposed by blending machine learning algorithms, natural language processing (NLP) and text analytics combined with organizational preferences. This framework gives a recommender system considering the user profiles, training preferences for his or her organization where each set of organizational units will have unique training recommendation requirements considering organizational functional behavior. The proposed mechanism uses machine learning algorithms at different stages of its learning process and ensemble them in a unique fashion such that desirable results are achieved to the user satisfaction.
Factors Affecting CO2 Absorption in Water Using a Gas Absorption Packed Column
Authors: Al Hadhrami Maitha Zuhair , Alalaween Mohammad Abdel Fattah , Mateo Antonio Lugay , Al Blooshi Abdulmajeed Abdulla , Kahoor Khalid Yousuf , Al Yileili Saeed Ali , Al Suwaidi Rashid Salem 
Published: March 2023

AbstractPopulation growth is directly associated with increase in energy demand. Amplification in industrial activity has led to a drastic escalation in greenhouse gas emissions causing global warming. The major gas involves carbon dioxide, accounting for 76% emitted from different industrial sectors. The oil and gas industry alone is responsible for 90% of these emissions. Removing CO2 is a vital process in the gas industry which must be undertaken. Carbon capture utilization and storage (CCUS) technologies have evolved through the years due to the necessity of the current world-wide shared goal, to attain net zero.Several combustion methods have been developed to capture CO2 during actual operations at fossil fuel power plants, at natural gas processing plants and at coal gasification plants. However, methods that are based on chemical and physical absorptions have been most widely used. One example is the gas absorption-based method which requires low energy consumption and has been proven to be cost-effective. Using certain water types, mixed with minute concentration of chemical solvent, it can readily absorb CO2. This approach will be used in the following research study to investigate gas absorption rate using different water samples that pass through a packed column, thereby enhancing the mass transfer of gas component.In this study, the gas absorption experiments were carried out using SOLTEQ gas absorption unit containing DN 80 packed column with glass Raschig rings and with an effective column height of 1000 mm (Figure 1). Under constant operating conditions, the temperature and pressure were set to 24°C and 2 bars, respectively, to investigate the impact of pH level and conductivity of various types of water on CO2 absorption at different gas flow rate.The statistical analysis indicates that TDS and conductivity have a stronger correlation with gas absorption (P=0.99) than pH (P=0.76). The average CO2 absorption of the three samples at different flow rates (e.g., 0.8, 1.3, and 2.2 LPM) ranged from 36.40 in sample 1 to 69.50 in sample 2 at flow rate 2.2 LPM. Overall, samples 2 and 3, neutral to base with pH value of 7.25 and 8, respectively, have a statistically significant negative correlation with average CO2 absorption, whereas the acidic (pH = 5.42) sample 1 has significant positive correlation between the two variables (R2 = 0.99).Overall, samples 2 and 3, which are neutral to base with pH values of 7.25 and 8, have a statistically significant negative correlation with average CO2 absorption. In contrast, the acidic (pH = 5.42) sample 1 has a significant positive correlation between the two variables (R2= 0.99). This study provides optimal operating conditions for the CO2 absorption process. However, additional research is required to investigate the effect of other physical and chemical properties of water on CO2 absorption.