bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sustainable Aviation Fuel Investment and Feedstock Calculations by Microalgae Applications with Biorefinery Approach
Authors: Özdemir Irmak 
Published: October 2023

Abstract
Numerous studies have been created in recent years to establish a sustainable biofuel production industry to address the depletion of fossil fuels. This new industry must be effective (high productivity), financially successful (low production costs, which leads to reasonable fuel rates), and moral (low carbon balance).
Algae, one of the most significant sources of biofuel, can survive in a variety of ecosystems, including those found in freshwater and marine environments, desert environments, hot springs, and glacial environments. The kinds and combinations of photosynthetic pigments present in various algal species decide the systematics of algae. Microalgae have enormous potential for the creation of sustainable biofuels.
The expense of aviation fuel would approach economic viability if algae production could be scaled up to commercial levels, which would also result in a reduction in carbon emissions. That is more than enough motivation to compete with petroleum fuels, particularly when paired with existing policy support or consideration of coproduct opportunities, as well as promises from the international community to decarbonize aviation.
The study's objective is to use wastewater effluent to harvest biofuel from algae specie. Studies will be done in this context on the physiological and chemical characteristics of Arthrospira Platensis. Also, it will research and interpreted how much investment and feedstock is required if the airlines use sustainable aviation fuels.
Emphasis of High Order Stratigraphic Sequences Enabled by the Relative Geological Time Modelling Method: Application to Fractured Thin Reservoirs in a Pre-Salt Gas Field, Offshore Netherlands
Authors: Daynac N. 
Published: October 2023

Summary
The author describes the method and results of a global and automated approach for seismic interpretation (Pauget et al, 2009), applied to a pre-salt gas field of the Dutch Cleaver Bank High platform, offshore Netherlands. A sequence stratigraphic framework called ‘Relative Geological Time (RGT) model’ is built from the seismic data to emphasize structural and stratigraphic features. Basin and reservoir characterizations are thus enabled by RGT-derived advanced attributes, rock physics modelling, Wheeler diagrams and sub-sample stratal slicing. Several fault networks related to different tectonic phases are emphasized, key stratigraphic surfaces are delineated, and major facies trends of the pre-salt reservoir level are discriminated. Those outputs are finally used to assess the impact of fault networks and subsequent subsidence on the eustasy-controlled thin beds succession. The author ultimately demonstrates the potential of the global RGT modelling method to revise hydrocarbon fields and identify pre-salt siliciclastic carbon storage sites.
The Use of Artificial Intelligence (AI) to Give Insight to a Complex Well Tubing Issue to Ensure Suitable Corrosion Mitigation Approaches
Authors: Mohamed-Said M. , Cowe B. , Bertoncello A. , Oliveira-Martinez F. , Galliot L. 
Published: October 2023

Abstract
In one of TotalEnergies North Sea fields, nitrate is continuously injected as the main mitigation of reservoir souring. The nitrate treatment is employed to limit the biogenic generation of H2S, due to reservoir souring. Reservoir souring is caused by the proliferation of SulfateReducing microbes (bacteria and/or archaea).
In parallel, severe corrosion was observed in oil producing well tubing conveying fluids from a reservoir subjected to nitrate treatment. It is known that nitrates can catalyze the corrosion of carbon steels through different mechanisms, in particular electrochemical or microbiological. The challenge was therefore to accurately evaluate the impact of nitrate injection, and its presence in the produced fluids, on the corrosion of the producing well tubing.
The influence of nitrate treatment towards corrosion of carbon steel well tubing has been singled out using an artificial intelligence algorithm. The algorithm employs a method called "Propensity Score Matching" (PSM). PSM is a statistical method commonly used in the medicine field to assess the efficiency of treatment in biased data. This method has been used to compare two reservoirs, one being subjected to nitrate treatment and another that has never been subjected to nitrate treatment.
In this paper a first known use of causal inference in industrial settings is presented. It helped removing biases by comparing only comparable data and to find causal relationship in the data. Outcomes of the multi-faceted study have led to optimized corrosion mitigation approaches and increased well tubing service life.
Learnings from 150+ Autonomous Inflow Control Completions in 7 Unique Reservoirs in Sultanate of Oman
Authors: Ali Al-Jumah , Mahmood Harthi , Said Kindi , Yousuf Sinani , Nasser Azri , Ahmed Al Lawati 
Published: October 2023

Abstract
This paper summarizes the integrated subsurface technical learnings from the successful application of Autonomous inflow control Completions in long horizontal wells producing heavy oil in multiple fields in the south of Sultanate of Oman, it details the facts, observations, and insights the multidisciplinary authors have captured through initially piloting 4 trials to executing over 150 jobs in 7 unique reservoirs in the last few years utilizing multi-vendor equipment.
The technology in principle can precisely identify the fluid flowing through it and shutting-off the high water or gas saturated zones autonomously while stimulating oil production from healthy oil-saturated zones. The Autonomous Control valves can differentiate the fluid flowing through it via fluid properties such as viscosity and density at reservoir conditions, with a design based on Hagen-Poiseuille and Bernoulli's principles.
Based on the Integrated performance reviews, the technology has shown the benefit of accelerating oil production as well as reduction of unwanted water which not only reduces the OPEX of these wells but at the same time has an enormous positive impact on the environment and Green House Gases (GHG) emissions. Majority of the wells completed with this technology started with a relatively lower water cut and are still producing with low water cut and higher oil production as compared to other direct analogs neighboring wells. Also, from initial field-wide assessment, it is envisaged that this technology will assist in producing more oil sooner i.e. acceleration, improving overall recovery v time. Also, the technology helped in mitigating the facility constraints of handling produced water which allows the continued drilling of field development activities to drill in-fill wells. Only installations in New wells will be discussed here.
The multidisciplinary authors have summarized the results from this technology deployment in multiple oil fields and presented it in this article as a practice worth replicating in a similar heavy oil environment, due its many benefits in optimizing field development and performance. This article will not focus on the theory and design of the technology, but rather the practical aspects of implementation and the impact on wells performance. Please refer to "further reading" for details on theory as well as more info on installations in existing wells.
Qualification of an Emerging Class of AICDs with Artificial Gravity: The Density-AICD Technology
Authors: El Mallawany Ibrahim , McChesney Ryan , Greci Stephen , Novelen Ryan , Corona Georgina , Warren Caleb , Asthana Pranay , Bukhamseen Ahmed 
Published: October 2023

Abstract
Conventional Autonomous Inflow Control Devices (AICDs) use the downhole viscosity contrast between wanted and unwanted fluids to preferentially produce one while restricting the other. Effectivity of these conventional AICDs is limited in light oil reservoirs where the difference in viscosity between oil and water is small or nonexistent. This paper describes an autonomous device that allows or impedes flow based on fluid density. It also presents the qualification testing program completed to advance the Density-AICD from a development concept to a commercially available product.
The Density-AICD distinguishes between produced fluids at downhole conditions using an innovative buoyant float design with an effective density between oil and water. Production flow through the device generates an artificial gravity, amplifying the buoyant force used to control the Production Valve altering the tool's inflow rate. The fluid selector feature operates independent of Earth's gravity eliminating the need for downhole orientation in the completion.
The performance of this novel tool has been demonstrated through computational numerical simulations, small scale sub-component testing, and a full-scale qualification test program. Sub-component and system level tests performed to evaluate fit for purpose and reliability included: Production Valve cycle and erosion testing, bearing erosion testing, National Association of Corrosion Engineers (NACE) component testing, pressure testing of a wash-pipe-free feature, system erosion testing, and flow performance for single and multi-phase flow.
Density-AICD flow loop testing demonstrated substantial restriction to unwanted fluids based exclusively on density contrast. Test data showed a higher ratio of oil to water production than the initial design requirement and confirmed the ability of the device to toggle between open and closed positions depending on the surrounding fluid. A subsequent flow and function test was conducted after subjecting the tool to erosion testing with a negligible effect on performance and functionality.
This paper will present the activities completed to qualify the Density-AICD technology and the benefit of the technology in very-light oil reservoir applications.
Innovative Molecular Sponges: Next-Generation Direct Air Capture Technology Enabled by Metal-Organic Frameworks
Authors: Cruz A. J. , Parrella I. , Wenz G. , Storey J. , Husk J. 
Published: October 2023

Abstract
Direct air capture (DAC) is an engineered atmospheric carbon dioxide (CO2) removal technology aimed at mitigating climate change impacts, as emphasized by the United Nations Framework Convention for Climate Change (UNFCCC). With only a limited number of currently deployed units globally, DAC technology is still at its embryonic stage. To improve its acceleration, the DAC system needs to be tackled holistically – including but not limited to (1) sorbent selection and performance improvement, (2) scaling of manufacturing from laboratory to industrial segments, and (3) integration of the engineered contactor design. Metal-organic frameworks (MOFs), with their interesting properties, such as record-breaking specific surface areas, crystallinity, and chemical versatility, are identified as one of the most promising materials for solid DAC applications. Baker Hughes recently acquired Mosaic Materials to scale its next-generation DAC technology. In this work, Mosaic's breakthrough will be used as a case study, building on its proprietary MOF, process optimization, and engineering design, and the journey from lab-scale work to systems-level programs. Policy, sustainability, and knowledge-sharing will play critical roles as prime agents to accelerate DAC deployment enabled by advanced materials such as MOFs.
Research on Geophysical Response Analysis and Geostress Prediction Technology Based on Seismic Azimuthal Anisotropy
Authors: Wang Chang , Shi Xuewen , Wu Jianfa , Zhang Dongjun , Liao Maojie , Zhang Ruhua 
Published: October 2023

Abstract
The exploration and development potential of shale gas reservoirs in Sichuan Basin is enormous, however it also faces difficulties such as complex structures, strong heterogeneity and unclear geophysical response characteristics. Fine prediction of geostress is an important part of shale gas exploration and development, which directly affects the implementation effect of reservoir evaluation, well trajectory design and fracture reconstruction. The existing geostress prediction techniques lack high precision seismic data constraints, making it difficult to accurately reflect the planar distribution characteristics of the geostress in block with rapid changes in complex tectonic zones. At the same time, the geophysical response characteristics of geostress in Sichuan Basin are unknown, the geostress seismic prediction technology lacks theoretical basis. This paper combines numerical simulation and physical experiments, and defines the characteristics of geophysical response of shale gas reservoir in Sichuan Basin changing with stress field, and technical countermeasures for geostress seismic prediction are established to provide technical means for accurate prediction of geostress field in shale gas block. Based on the geostress sensitive parameters obtained from prestack seismic inversion, the geostress field prediction of a Shale gas work area in Sichuan Basin is realized.
Combining Machine Learning and a Multiphase Flow Model for Hybrid Virtual Flow Metering
Authors: Gryzlov A. , Safonov S. , Krasnopolsky B. , Arsalan M. 
Published: October 2023

Abstract
Virtual flow metering is a technology for indirect estimation of multiphase production rates. The most straightforward approach to obtain virtual measurements is to apply machine learning models, which enable fast but not necessarily accurate prediction of flow rates. In order to overcome any related limitations machine learning methods can be combined with physical conservation laws of mass, momentum and energy. The resulting hybrid virtual flow metering approach strongly relies on the capabilities of underlying physical simulator.
In this work various approaches of combining measurements with multiphase flow models are investigated. It is demonstrated that a wellbore flow model has a central role in any type of hybridization scheme which connects the available measurements to the target flow rates. Due to specific requirements of the virtual flow metering applications, this simulator has to be fast and accurate enough to qualitatively describe flow in wellbores and pipelines. In this work, such a simulator is presented, which is based on a one-dimensional formulation for mass and momentum conservation, but contrary to other commercially available options, the current development is based on a drift-flux approach, which is less demanding on the interfacial closure terms and can be more easily tuned with field data. The performance of the simulator has been evaluated using a set of transient benchmark scenarios, where the reasonable match against the reference data has been demonstrated.
The simulator is applicable to a wide range of multiphase flow problems of practical interest and uses advanced numerical algorithms to ensure robustness and performance. The closure relationships can be adjusted to improve the performance for a particular well. In addition, a dedicated graphical user interphase enables user-friendly interaction for setting up the computational case and processing the output production data.
Rock Type-Based Geosteering in a Multilayered Reservoir by Combining LWD NMR Measurements and Ultradeep Azimuthal Resistivity Images
Authors: Al-Otaibi A. , Osman H. , Van Steene M. , Santoso G. 
Published: October 2023

Abstract
Deep-azimuthal resistivity images are widely used to place wells accurately inside of a target reservoir structure. However, the resistivity measurement does not provide much sensitivity to the reservoir quality, particularly in carbonates, where large pore-size variations are often encountered. For optimized well placement, combining the deep-resistivity images with logging-while-drilling (LWD) nuclear magnetic resonance (NMR) measurements establishes the link between reservoir structure and rock types while drilling.
Factor analysis is the technique used to reduce the large NMR data set to a smaller number of underlying, porofluid components. These components are clustered into groups called porofluid facies, which reflect the most common combinations of pore volume and fluid NMR properties. Based on the NMR data, four petrophysical rock types are generated while drilling: RT-1 has good porosity and long T2 components, indicating large pores; RT-2 also has good porosity but medium T2 components, indicating smaller pores; RT-3 has medium porosity and long T2 components, while RT-4 has medium or low porosity and medium or short T2 components, indicating the poorest facies.20
The NMR-based rock typing technique and ultra-deep resistivity images were combined in three laterals drilled back-to-back in a thin-carbonate reservoir where pore size variations were expected. In the first lateral, targeting layer 10, fair (RT-2) rock type was present over the first half of the lateral. Only a small part of the drilled footage encountered the best rock type RT-1. The decision was then made to explore layer 11 under layer 10. The NMR showed that layer 11 was mostly of the poorest quality (RT-4). Based on the first lateral results, the second lateral targeted layer 10. Layer 10 was found to be of excellent quality in which most of the rock was RT-1 type, with some sections of RT-2; hence, no change of layer was required in this lateral. The third lateral explored layer 5. The first half of the section encountered RT-2 and RT-4 types. After having observed that a resistivity increase corresponded to a poorer rock type, the second part of the lateral was completed in one layer that intersected RT-1 and RT-2.
Combining NMR rock typing with reservoir delineation by means of deep-azimuthal resistivity images while drilling is a new methodology that combines the strengths of both techniques to optimize well placement and reservoir understanding. One example is a well that has three laterals, which illustrates this technique; each lateral was placed not only in the best rock type, but also in the target structural location.
An Integrated Geomechanical Approach in Mud Loss Pressure Prediction in a Giant Oil Field in Offshore Abu Dhabi
Authors: Tsusaka K. , Toma M. , Goraya Y. G. I. , Fujita K. , Nakayama S. , Saito S. , Fukuda K. , Toki T. , Matsubuchi H. 
Published: October 2023

Abstract
In a giant oil field in offshore Abu Dhabi, the intermediate hole section has suffered from borehole instability in highly laminated shale, mud loss in leaky carbonate and high reservoir pressures. Appropriate control of equivalent circulation density (ECD) is a key for safer drilling to the target reservoir. The present study aimed at analyzing the mud loss pressure in the leaky carbonate which is the allowable limit of ECD in the hole section. The study investigated spatial distribution of mud losses and variation in ECD at mud loss based on review of drilling operation in nearly 560 boreholes. The geomechanical models were built in five key locations. The area in which vuggy and fractured carbonates are distributed was interpreted based on the seismic interpretation. The mud loss pressure in the carbonate formation was analyzed based on the comparison of formation breakdown pressure and the minimum in-situ stress (S3) with ECD applied in drilling. The study proposed a map of mud loss pressure in the leaky carbonate in the six regional divisions in the studied field. The P90 and P50 values of the mud loss pressure in each region were analyzed by using the geomechanical models. The P90 value was analyzed by comparing ECD at mud loss with the magnitude of S3 in each region. Mud losses are highly likely to be prevented by controlling ECD under the P90 value in each of the regions. The P50 value was estimated by analytical solution which considers the effect of natural stress cage due to stress redistribution and thermal stress due to cooling effect by drilling fluid in near-borehole wall area. The P50 value was represented in a polar plot since regional variation in the rock mechanical characteristics and in-situ stresses and borehole direction were considered. The map functions as a guide for the design of mud weight in the ongoing drilling campaign. The P90 value is applied to the standard design. The P50 value is referred to as the upper limit in the case that excessive borehole instability in the shale or kick in the reservoirs is expected by applying the P90 value. If ECD above the P50 value is expected, additional casing should be considered to secure the loss zone before penetrating collapsing shale and high-pressure reservoirs.
Plunger Lift Application in Packer Wells – Success Stories, Challenges & Lessons Learnt
Authors: Khan Z. H. , Hafeez Q. , Ahmed R. , Memon S. A. , Khan R. A. 
Published: October 2023

Abstract
This paper focuses on the effective application of plunger lifts in gas wells with packer completions. Such wells present unique challenges, and the study aims to shed light on the successful use of plunger lift under these conditions. The paper delves into the complexities encountered during operations and emphasizes the opportunities to optimize recovery rates by reducing abandonment thresholds. The study also highlights the key lessons learned throughout the entire process, providing valuable insights to industry professionals working in similar contexts.
The deployment of plunger lifts as a project within the current portfolio was undertaken to optimize gas recovery from pre-existing fields. An all-inclusive approach was taken to meticulously determine the wells suitable for potential installation, resulting in 17 such installations. These cases illustrate the obstacles encountered during the installation process and the methodologies employed to surmount them. The efficacy of plunger lift in wells utilizing packers is influenced by several variables, including the need for a high gas-liquid ratio as compared to packer-less completions, sole reliance on tubing energy for plunger cycling, the avoidance of severe slugging flow regimes, and the lack of casing pressure monitoring.
Following initial trials in 2021 and 2022, a total of 17 plunger systems were installed, yielding highly favorable outcomes in terms of production resurgence, amounting to approximately 5-6 MMCFD from load-up and shut-in wells, coupled with an additional 6.5 BCF of gas and 50 MBC of condensate reserves. Project economics indicate a net present value of approximately 9.7 MM USD, versus a capital expenditure of approximately 1.5 MM USD. The case studies featured in this work underscore the effectiveness of plunger lift systems that utilize packer completions, emphasizing the criticality of precise design and operation of the system for optimal performance. Furthermore, this research outlines several post-installation challenges, including rapid inflow, insufficient energy for plunger cycling, large liquid slugs, and the necessity for plunger lift monitoring and mitigation. Overall, this study offers valuable insights into the design and operation of plunger lift systems in conjunction with packer completions, underscoring the continued requirement for research and innovation in this area to improve gas production in these wells.
An innovative aspect of this research is creating selection criteria for packer completions, which underwent further refinement based on insights gleaned from installations. These criteria include DAGLR, velocity profile, flow regime, slug volume, fluid level, and wellbore restrictions. In addition, shut-in pressure trends and plunger arrival data were employed to monitor and optimize plunger lift performance. However, monitoring plungers in packer completions remains an area of study for effectively enhancing plunger lift performance.