bluuebunny/crossref_metadata_2025_split huggingface dataset:
Tubing Conveyed Perforation in a Highly Sour High Pressure Horizontal Well in Sultanate of Oman
Authors: Al Balushi S. , Charushin A. , Maskari S. , Guzman R. Castiblanco , Al Busaidi Q. , Al-Lawati H. , Al-Sukaiti A. , Al-Breiki I. , Al-Taiwani M. , Al-Nadhairi N. 
Published: April 2024

Abstract
The Yibal Khuff field is located in the North of Sultanate of Oman and is renowned to be part of the second largest and most technically complex project in Petroleum Development Oman's history. The target oil and gas wells are Highly Sour with High Pressures and Temperatures. This paper describes successful Tubing-Conveyed Perforation (TCP) in horizontal wells using Coiled Tubing, where over 100 m of additional reservoir was perforated boosting the production of wells existing perforations.
The coiled tubing attended the horizontal live well at highly sour and HPHT downhole conditions with a suspended height above 25 m. The approach was to manage the downhole environment prior to proceeding with the Tubing-Conveyed Perforation by controlling the bottomhole pressure. Once the downhole environment was addressed and controlled, the depth correlation took place using Memory CCL-GR to locate the required target zones. The main operation consisted of 10 repeated perforation runs at a gun length of 12m per run to accumulate a total of120m of perforation interval.
The well provided a combined challenge of highly sour environment, existing open perforations, high surface and high bottomhole pressures. Following a thorough analysis and selection criteria where multiple conveyance methods were considered and evaluated such as Eline Tractors, Tubing Conveyance with Rig/Hoist, E-Coil and Conventional Coil Tubing via Sand Jetting and deployment means, the selected method of intervention was Tubing Conveyed Perforation via Coiled Tubing. A combined approach of utilizing controlled intervention techniques enabled the increased production access to the hydrocarbon reserves. In addition to the inherent safety precautions, the project maintained quality assurance as another main driver resulting in flawless delivery of the project.
This solution provides an effective method of tackling perforating challenges in highly sour environments, where coiled tubing conveyed perforation was executed for the first time at a suspended height in a live horizontal well with open perforations. The bottomhole pressure was 4,600 psi and H2S above 3%. TCP via Coiled Tubing has proved to be a high production gain concept, where replication will be beneficial not only to Petroleum Development Oman but to the industry as a whole.
Advanced Robotics for Oil and Gas Applications
Authors: Al Ghafri H. , Saidi M. , Al Sulaimani M. , Al Habsi Z. S. , Al Abri H. 
Published: April 2024

Abstract
Robotics are revolutionizing the transformation of many industries across the globe; one is oil and gas industry. The industry has lately been under a huge pressure to stay efficient, safe, cost competitive and reliable. Therefore, new technologies and solutions have been a focus of companies in the industry to optimize and move on from their conventional practices to more efficient and reliable methods. Autonomous robotic vehicles equipped with advanced sensors, camaras & tools can perform complex and sophisticated maintenance and inspection tasks such as robotic tank cleaning & inspection, robotic UT inspection for elevated assets & robotic coating removal vehicle. These robots have gained the company benefits in both directly & indirectly reducing the cost and time and more efficient and comprehensive outcome. Finally, safety & environmental impact has been an optimum benefit out of using these robots which can easily be navigated into a hazardous confided spaces and high elevated assets.
Automated Engine Management and Monitoring with AI
Authors: Koritala C. , Avilala S. A. R. , Al Amin S. T. , Lakkaraju R. 
Published: April 2024

Abstract
Efficient power management in diesel-powered drilling rigs stands as a pivotal factor in operational efficacy, fuel cost, and emissions reductions. In this study, we concentrate on the criticality of maintaining diesel engines at higher loads to attain optimal performance. To realize the objective of sustaining diesel engines at higher load, in this paper, we present a comprehensive end-to- end solution. This solution encompasses multifaceted elements, a predictive framework for anticipating power demands, an evaluation of engine efficiency prediction, optimized fuel consumption and emissions, condition-based engine maintenance and the implementation of efficient engine start-stop methodologies.
We introduce a methodology to predict expected power demand, furnishing a proactive mechanism to manage fluctuating power requirements during drilling operations. The study also delves into predicting engine conditions, furnishing insights into maintenance scheduling and proactive measures to prevent potential issues. Effective engine start-stop techniques are elucidated as part of the overarching strategy to sustain engines at optimal load parameters.
The garnered insights underscore the successful adoption of Al-based automation across multiple rigs, yielding tangible benefits including automation, operator support, fuel economy, emissions reduction, and deployment across 68 rigs. Operating engines at higher, more fuel-efficient loads not only curtails generator runtime but also prolongs engine lifespan and reduces maintenance intervals. Moreover, in this paper, we emphasize the paramount significance of this approach of mitigating downtime linked to generator complications, providing a holistic view of the advantages and successful outcomes of the proposed comprehensive solution.
In conclusion, we furnish invaluable insights into engine management optimization in diesel-powered drilling rigs, conducting an intricate exploration of pivotal factors, methodologies, and lessons learned with a focal point on achieving efficiency, fuel savings, and emissions reduction.
A Proactive Geosteering Approach Integrating Advanced LWD Nuclear Magnetic Resonance and Deep Azimuthal Resistivity Tools for Landing a Deep Jurassic Horizontal Well in the Best Carbonate Reservoir Facies
Authors: Mohamed Said Beshry , Fahmy Mahmoud Fawzy , Nguyen Kim Long , Al-Mutairi Nami , El Masry Hisham , Sitinjak Eri , Shinde Neha 
Published: April 2024

The Jurassic Marrat formation in West Kuwait is a tight and heterogeneous carbonate reservoir in which petrophysical characteristics lead to a limitation in the predictability of reservoir properties. Landing a later well exposes operational risks, therefore LWD triple combo is excluded to avoid environmental issues and cost effects. Instead, LWD-NMR combined with Deep Azimuthal Resistivity tools emerges as the optimum solution to evaluate the formation and optimize well placement in the best reservoir quality.
NMR is utilized for accurate porosity because it is independent of lithology. The T2 distribution is a direct indicator of porosity and permeability. DAR is an azimuthal propagation resistivity tool that can greatly reduce the risk of misplacing the wellbore while drillingextended reach and complex 3D horizontal wells. Marrat reservoir tends to have high resistivity, but theporosity isn't always ideal. It makes geosteering operation more challenging if only gamma & resistivity logs are used to overcome this challenge, LWD-NMR in combination with DAR maximizes the reservoircontact and produces from the best reservoir quality.
Deep Azimuthal Resistivity shows the F-11 surface was found 25 ft. shallower than the A-1 plan. The plan was modified in real-time to ensure a successful landing within the target zone, the starting plan of 3.8 DLS was modified and increased to 4.65 DLS to account for the shallower F-11 with the aim of achieving a TVD depth of 20 ft. inside the reservoir zone. After landing the well at 90 deg inclination following the NMR & DAR signatures, we continue building the inclination angle to 90.5 deg to gently upwards cut stratigraphically across the section and to penetrate the optimum reservoir zone before leveling off gradually to 89.3 deg following NMR & DAR signature to maintain the well in the best reservoir facies. During the geosteering operation in the F-11 zone, a decrease in porosity from 16 pu to 2 pu was detected by the NMR. Consequently, a real-time adjustment was made to avoid the tight area and guide the well toward the sweet spot in the F-11 zone. The combination of NMR and DAR tools successfully landing of the well in the F-11 zone with high-confident hydrocarbon potential.
Assessment of Reservoir-Souring Potential of a Sour Middle Eastern Field Using a Quantitative and Predictive Approach
Authors: Salimi H. , Hadhrami M. 
Published: April 2024

Abstract
Souring potential of fields during depletion and waterflood developments needs to be investigated ahead to enable making sensible decisions on injection-water source, well material selection, and facility design. This paper presents the application of a novel reservoir-souring approach to assess the souring potential of a Middle Eastern field (B) that comprises two reservoirs (the "U" reservoir with a strong aquifer pressure support, and the "M" reservoir with negligible aquifer pressure support.
Both reservoirs produced sour fluids before the start of water injection, although the H2S levels in the U reservoir are much higher than those in the M reservoir. Because there is no sulfur-isotope data to determine the origin of the produced H2S, four possible hypotheses were proposed: (I) the reservoirs were initially sweet and bacterial-sulfate reduction (BSR) was triggered with drilling fluids; (II) the reservoirs were initially sour because of non-microbial geological sources and BSR has occurred since the start of waterflooding; (III) the same as hypothesis II but BSR has happened since drilling, and (V) the reservoirs were originally sour because of bacterially mediated sulfate reduction during early diagenesis. Each of these plausible hypotheses were modeled to history match the historical H2S and to predict future souring levels.
A comparison between the simulated and historical H2S concentrations indicates that these two out of the four proposed hypotheses are more likely to explain the origin of the produced H2S, viz., (I) the reservoirs were initially sweet, but BSR was triggered with drilling and continued with production given that all the reservoir and environmental parameters were in favor of microbial activities, or else (II) the reservoirs were originally sour because of a non-microbial source, and then BSR has been occurring with water injection. However, because the H2S-abstraction capacity only plays a role in hypothesis (I), sensitivity analysis was performed on this hypothesis.
The different H2S levels in the U and M reservoirs as well as in different wells can be attributed to different H2S abstraction capacities of the reservoir rock.
Sensitivity runs reveal that for the U reservoir that waterflooding is not effective, the nutrients content of the formation water and the H2S-abstraction capacity have significant impacts on the max H2S concentration. However, for the M reservoir with waterflooding, the sulfate content of the injection water and the injection rate in addition to the aforementioned parameters have significant effects on the max H2S concentration.
Innovative Thermal Well Completion Design Yields Substantial Enhancement in Steam Injection Capacity
Authors: Al Amri Y. B. , Al Bulushi Z. A. 
Published: April 2024

Abstract
The QAS thermal development is one of the most productive fields in the Sultanate of Oman. The field's fractured reservoir has got a gas cap within excess of 3% H2S which makes it PDO's riskiest asset to be attended by well engineering operations. This paper will introduce two of the most innovative design optimizations which were implemented for the first time: Semi-Flush 5.5" Steam Completion and 7" Steam Completion
The main challenges that were mapped out and tackled during the implementation were, the 7-production casing ID limitation and the gas cap procedures and mitigations (Known as Natih requirement). In order to overcome the above challenges, a detailed engineering design was carried out for the casing string, connections and the tubing hanger. This paper will explain the detailed engineering approach from design to execution. The main elements discussed are, the design aspects of the 7" and Semi-Flush 5.5" strings, the annulus fluid replacement for annulus pressure build and using retrievable seal bore packer with bore extension under total losses.
In the initial 2 trials for the 5.5" steam completion, steam capacity was increased by 50%. This design will be applied to the full remaining scope of 15 existing wells. Also, the 7" steam injection completion was trailed in 2 wells. As a result, extra steam injection capacity has been added to fleet by converting gassed out producers to steam injectors. The highlight of the project was that with the 7" injection tubing, the steam injection capacity increased significantly and eliminated the need of drilling 4 new steam injectors, marking a considerable cost saving to the company. Avoiding the need of drilling new injectors also reduced the HSE exposure that is associated with high-risk wells with a risk of encountering sour shallow gas. Also, eliminating the dynamic fill for the upper part of the completion reduced Natih type operations which in turn reduced HSE exposure for future workovers significantly.
The Semi-Flush tubular with premium connections were used for the first time in the steam application to accommodate the limited annulus clearance between the steam injection tubing and the production casing strings. As well, repurposing of legacy gassed-out oil producers to 7" steam injectors whereby the 7" thermal completion was run for the first time. Also, deployment of thermal Retrievable Seal bore Packers enables future interventions without exposure to the sour gas cap from a naturally fractured carbonate reservoir.
CO2-Driven Geothermal Energy Extraction in the Baram Basin, Sarawak: Insights from Numerical Reservoir Simulations
Authors: Bataee M. , Chai M. C. , Bennour Z. , Carter R. , Hamdi Z. , Hassan A. M. 
Published: April 2024

Abstract
This progress report focuses on the potential for geothermal energy extraction in Malaysia, particularly in the Sabah and Sarawak sedimentary basins. Despite the region's rich deep reservoirs, development in this area has been limited. Our study emphasizes the extraction of geothermal energy from the Sarawak Basin's geothermal reservoirs through CO2 injection. We primarily investigate sandstone formations, analyzing their properties and the feasibility of hot water extraction using CO2. The report provides a theoretical framework to understand the primary recovery mechanisms for fluid extraction from these reservoirs. To simulate geothermal reservoir performance, a commercial reservoir simulator was used. Due to the lack of precise data, our analysis relies on existing literature and estimations, which are substantiated by relevant sources to ensure reliability. We constructed a reservoir model to compare scenarios with and without CO2 injection, demonstrating that CO2 injection significantly enhances energy extraction. Our findings also suggest that sandstone formations can effectively trap CO2, offering a dual benefit of permanent underground storage and improved fluid production from the reservoir. Lastly, the report identifies areas for further improvement in this field.
Modeling of Gas in Riser Unloading Problem
Authors: Ashena Rahman 
Published: April 2024

Abstract
A Gas-in-Riser (GIR), when not predicted and controlled, expands and reaches the surfaces in an uncontrolled manner to cause unloading of the riser and finally a blowout, which was the case with Deepwater Horizon's 2010. Failing to predict and model GiR fluid flow would jeopardize well control. Such a model is vital for efficient performance of riser gas handling (RGH) systems, but it is still a challenge for the offshore industry. Therefore, in this work an analytical model was found for gas migration in riser with water-based muds, based on gas laws. However, the model cannot converge from a specified time/depth on. This is considered a challenge for developing a straightforward fluid flow model that can handle modeling gas flow in the riser. Therefore, this work finds an analytical model which can not only outperform iterative models but can also find the riser equilibrium depth for a real gas. Since backpressure is considered in the developed equations, it can be used for riser gas handling (RGH) systems. The root cause of inefficiency and impracticality of gas law models above the equilibrium depth is still unclear; thus, to provide a more reliable gas migration modeling it is recommended to further study the root cause and apply more sophisticated CFD methods to compare with gas laws’ results.
Asset Integrity AI & ML Applications in Gulf of Mexico
Authors: Majors Marc , Ferguson Eric , Bargoti Suchet 
Published: April 2024

Abstract

Objective
Risk reduction and increased Fabric Maintenance efficiency using Artificial Intelligence and Machine Learning algorithms to analyze full-facility imagery for atmospheric corrosion detection and classification. Following imagery capture and processing, deficiencies are identified, and targeted mitigation strategies are executed at greatly reduced cycle time and cost.

Methods, Procedures, Process
A pre-mobilization facility scan plan is generated to maximize imagery quality, including high elevation scan positions, to ensure thorough and comprehensive analytics. Data from all scan positions are stitched together in a point cloud and aligned for accuracy relative to each location. Finalized imagery and point clouds are then tagged with unique piping line numbers per design, fixed equipment tags, or unique asset identification. The Machine Learning algorithm is intensely trained with manual ground truth inputs prior to analysis. The algorithm analyzes each pixel throughout the facility and detects, classifies, and reports on all identified corrosion, tagging faults to specific piping or equipment.

Results, Observations, Conclusions
Atmospheric corrosion is the number one Asset Integrity threat in the Gulf of Mexico. Utilizing this tool, we can have a comprehensive and objective analysis of a facility's health in a matter of weeks from the time of data collection. Data collection for a large deep-water, spar facility requires approximately 12 days with 8 data scanning personnel. Conventional manual inspections incur higher risk, higher cost, and reporting is much less objective considering the number of inspectors involved and the duration of a full-facility campaign. Finally, all results are published in a user-friendly dashboard that can be filtered by process type, equipment type, corrosion severity, and many other criteria as the user requires. Each fault is associated with the specific equipment identification and the user can navigate to see the imagery of the corrosion in a 3D, photogrammetric environment. Remediation strategies can be collated into work packs for fabric maintenance teams, further Nondestructive Examination (NDE) assessment, or work orders for replacement. Fabric maintenance efficiencies are substantially realized by targeting decks, blocks, or areas with the highest aggregate surface areas of corrosion (on process equipment or structurally, as selected by the user) and concentrating remediation efforts on at-risk equipment.

Novel/Additive Information
This application of Artifical Intelligence and Machine Learning is a first-in-industry approach to having a comprehensive understanding of facility coating integrity and external corrosion threats. HSE analysis, Risk awareness, and targeted remediation strategies will make the Asset Integrity program more efficient, proactive, and reduce down-time across the Gulf of Mexico related to atmospheric corrosion.
H2S Valorization Technologies to Produce Hydrogen from Unconventional Highly Viscous Oil Reservoirs: Moving Forward to the Production of Clean Fuels in Venezuela
Authors: Rodriguez Fernancelys , Belhaj Hadi , AlDhuhoori Mohamed , Alhameli Fatima , Morales Raifel 
Published: April 2024

Abstract
The production of clean fuels in Venezuela is currently a great challenge, since the country has huge reserves of hydrocarbons (mainly highly viscous) where acid gases such as hydrogen sulfide (H2S) are generated due to high temperatures involved in the production process (e.g. after the application of thermal processes). H2S represents a considerable risk to human life and the environment, in the same way that it causes corrosion and other flow assurance issues and potential damage to facilities and equipment. The objective of this article is to perform a state-of-the-art review of H2S conversion techniques from hydrocarbon reservoirs in Venezuela that allow the production of hydrogen and low carbon fuels, as wells as less toxic products with greater commercial value. Among the most widely H2S valorization techniques reported in the literature are thermocatalytic splitting, hydrogen sulfide methane reformation (H2SMR), non-thermal plasma, and electrolysis. At present most of these technologies are at research scale to provide good understanding and advancement on their fundamental process mechanisms as well as potential avenues for applications. For the Venezuelan case, thermocatalytic splitting is one of the techniques that has been widely studied from combustion tests, using extra-heavy crudes from the Orinoco Oil Belt and nanoparticle catalysts. Results of the review of this article show that the techniques based on the use of catalysts allow the production of H2 and by-products of commercial value for the petrochemical industry (i.e. carbon disulfide), one of the critical points being the selection of the most suitable catalyst along with temperature control. In the case of Venezuelan unconventional reservoirs, the separation of hydrogen from the reservoir's fluids to the surface conditions, for which membrane absorption techniques are required, as well the management of scales, etc. are some of the important and challenging aspects to take into consideration in the
development of the technology at field conditions. This article opens opportunities to produce hydrogen by thermal cracking at reservoir conditions for unconventional highly viscous oil reservoirs. It will highlight important technologies and applications in Venezuela and worldwide; and as such, this work will serve as a guideline for the evaluation of H2S conversion to H2 technologies from lab to potential field implementations.
Impact of a Vertical Temperature Gradient on H2S Gradient in Sour, Near-Critical Reservoir Fluids
Authors: Shaikh J. A. , Murata K. , Kuramata H. , Mogensen H. K. 
Published: April 2024

Abstract
An equation of state model is presented, developed for an H2S-rich field, where the fluid type changes smoothly from gas to oil through a zone with a critical fluid and not through a classical gas-oil contact with a discontinuity in fluid properties. For use in connection with compositional reservoir simulation studies, a depth gradient model has been developed that provides a good representation of the compositional variation with depth, including the depth where the fluid type changes from gas to oil. The depth gradient model considers the influence of both gravity and the vertical temperature gradient on the distribution of the individual components in the fluid column. A depth gradient model that only considers gravity and ignores the temperature gradient will simulate an increasing H2S concentration with depth, while the fluid samples show that the H2S concentration decreases with increasing depth. When the effect of the temperature gradient is included, a good match is obtained of the development of fluid composition, saturation point and GOR with depth.