bluuebunny/crossref_metadata_2025_split huggingface dataset:
Lateral Buckling Mitigation in Deep Waters - A Total Installed Costs Comparison
Authors: Priyadarshi Hemant , Fudge Matthew , Brunner Mark , Jose Seban , Weakly Charlie 
Published: August 2021

Abstract
The paper introduces lateral buckling mitigation techniques (sleepers, distributed buoyancy sections, and residual curvature method or RCM) used in deep water fields and provides a total installed cost comparison of these solutions in relative terms. A hypothetical deep-water scenario is used to compare all techniques within the same site environment. Historic benchmarks have been used to make a relative comparison of these buckle mitigation methods on the engineering, procurement, fabrication, and installation fronts.
In addition, risks associated with engineering, procurement/fab and installation have been listed to illustrate the risks versus rewards tradeoff. While sleepers and distributed buoyancy have been previously used in deep water, RCM doesn't have a significant track record yet. RCM is a proven and cost-effective buckle mitigation solution in shallow water. This paper compares its application in deep water to the prevailing buckle mitigation methods and confirms if it creates value (savings and reduces risks) for an offshore installation project. It is assumed that each mitigation method is appropriate for the hypothetical deep-water scenario.
Qualification of AM-Parts for The Offshore Industry
Authors: Moe Ole-Bjørn Ellingsen , Benoit Maillon Bertrand Henri 
Published: August 2021

Abstract
Use of additive manufacturing (AM) technology is quite mature in medicine and aerospace industries but adoption of the technology has been limited in the oil and gas industry. One of the reasons behind the slow adoption is the non-availability of industry standards and recommended practices. DNV aims to help the adoption of AM in the oil and gas industry by providing the needed industry standards and recommended practices. DNV is one of the largest classification societies in the world and provides classification, technical assurance, software and independent expert advisory services to the maritime, oil & gas and energy industries.
DNV has been running several projects globally to help the industry qualify materials and products produced by additive manufacturing. DNV has been working since January 2018 together with main stakeholders in a joint Industry Project (JIP) to develop requirements necessary to introduce components made by AM for oil and gas and related applications. The outcome of the JIP was released to the industry in 2020; a standard that describes the qualification and quality assurance of AM parts. The AM technologies addressed in the standard are laser based powder bed fusion (PBF-LB) and wire arc additive manufacturing (WAAM).
In this paper, the standard is presented, and a systematic way to qualify parts made by PBF-LB and WAAM technologies described. A case study, leading to a qualified part according to the standard will be presented. It has been led by Vallourec, a world leader in tubular solutions for the energy sectors. Vallourec embraced additive manufacturing a few years ago and is currently developing and offering WAAM components for various industries.
Real-Time Prediction of Choke Health Using Production Data Integrated with AI
Authors: Alghamdi Ahmed , Ayoola Olakunle , Mulhem Khalid , Otaibi Mutlaq , Abdulraheem Abdulazeez 
Published: August 2021

Abstract
Chokes are an integral part of production systems and are crucial surface equipment that faces rough conditions such as high-pressure drops and erosion due to solids. Predicting choke health is usually achieved by analyzing the relationship of choke size, pressure, and flow rate. In large-scale fields, this process requires extensive-time and effort using the conventional techniques. This paper presents a real-time proactive approach to detect choke wear utilizing production data integrated with AI analytics.
Flowing parameters data were collected for more than 30 gas wells. These wells are producing gas with slight solids production from a high-pressure high-temperature field. In addition, these wells are equipped with a multi-stage choke system. The approach of determining choke wear relies on training the AI model on a dataset constructed by comparison of the choke valve rate of change with respect to a smoother slope of the production rate. If the rate of change is not within a tolerated range of divergence, an abnormal choke behavior is detected.
The data set was divided into 70% for training and 30% for testing. Artificial Neural Network (ANN) was trained on data that has the following inputs: gas specific gravity, upstream & downstream pressure and temperature, and choke size. This ANN model achieved a correlation coefficient above 0.9 with an excellent prediction on the data points exhibiting normal or abnormal choke behaviors. Piloting this application on large fields, where manual analysis is often impractical, saves a substantial man-hour and generates significant cost-avoidance. Areas for improvement in such an application depends on equipping the ANN network with long-term production profile prediction abilities, such as water production, and this analysis relies on having an accurate reading from the venturi meters, which is often the case in single-phase flow. The application of this AI-driven analytics provides tremendous improvement for remote offshore production operations surveillance.
The novel approach presented in this paper capitalizes on the AI analytics for estimating proactively detecting choke health conditions. The advantages of such a model are that it harnesses AI analytics to help operators improve asset integrity and production monitoring compliance. In addition, this approach can be expanded to estimate sand production as choke wear is a strong function of sand production.
Real-Time Water Injection Monitoring with Distributed Fiber Optics Using Physics-Informed Machine Learning
Authors: Sadigov Teymur , Cerrahoglu Cagri , Ramsay James , Burchell Laurence , Cavalero Sean , Watson Thomas , Thiruvenkatanathan Pradyumna , Sundin Martin 
Published: August 2021

AbstractThis paper introduces a novel technique that allows real-time injection monitoring with distributed fiber optics using physics-informed machine learning methods and presents results from Clair Ridge asset where a cloud-based, real-time application is deployed. Clair Ridge is a structural high comprising of naturally fractured Devonian to Carboniferous continental sandstones, with a significantly naturally fractured ridge area. The fractured nature of the reservoir lends itself to permanent deployment of Distributed Fiber Optic Sensing (DFOS) to enable real-time injection monitoring to maximise recovery from the field. In addition to their default limitations, such as providing a snapshot measurement and disturbing the natural well flow with up and down flowing passes, wireline-conveyed production logs (PL) are also unable to provide a high-resolution profile of the water injection along the reservoir due to the completion type. DFOS offers unique surveillance capability when permanently installed along the reservoir interface and continuously providing injection profiles with full visibility along the reservoir section without the need for an intervention.The real-time injection monitoring application uses both distributed acoustic and temperature sensing (DAS & DTS) and is based on physics-informed machine learning models. It is now running and available to all asset users on the cloud. So far, the application has generated high-resolution injection profiles over a dozen multi-rate injection periods automatically and the results are cross-checked against the profiles from the warmback analyses that were also generated automatically as part of the same application. The real-time monitoring insights have been effectively applied to provide significant business value using the capability for start-up optimization to manage and improve injection conformance, monitor fractured formations and caprock monitoring.
Three-Phase Flow Profile Determination of A Horizontal Well in Offshore by Tracer Technology
Authors: Katashov Alexander , Novikov Igor , Malyavko Evgeny , Husein Nadir 
Published: August 2021

Abstract
Over the past few years, the oil and gas industry has faced a situation of high fluctuations in hydrocarbon prices on the world market. In addition, the trend for the depletion of traditional hydrocarbon reservoirs and the search for new effective solutions for the management and control of field development using horizontal and multilateral wells is still relevant.
The most common method for horizontal wells testing is production logging tools (PLT) on coiled tubing (CT) or downhole tractor, which is associated with HSE risks and high cost, especially on offshore platforms, which limits the widespread use of this technology. The solution without such risks is the method of marker well monitoring, which allows obtaining information about the profile and composition of the inflow in a dynamic mode in horizontal wells without well intervention.
There are several types of tracer (marker) carriers and today we will consider an approach to placing marker monitoring systems as part of a completion for three-phase oil, water and gas monitoring.
Hydrate Management Strategy for Subsea Development in Gulf of Mexico
Authors: Soroush Samaneh , Lu Debbie , Golczynski Tommy , White Christopher Jake , Spratt Tony 
Published: August 2021

Abstract
Gas hydrate formation in natural gas systems and subsea infrastructure can block pipelines and instruments, restrict flow, and lead to safety and environmental hazards in production and/or transportation systems. These problems can lead to substantial economic and HSE risks. Therefore, understanding how, when and where hydrate formation occurs are important factors in developing the hydrate management strategies. This paper addresses the hydrate management strategy in one of the subsea developments in the Gulf of Mexico (GOM). The effects of salinity, water cut, and amount of methanol on hydrate formation and plugging risk were studied in this paper. The experimental results and modeling in advanced thermodynamics software showed that an increase in the concentration of methanol and salts in the autoclave cell leads to a shift of the equilibrium curves, reducing subcooling and hydrate volume fraction while increasing induction time. The results also show that for some under-inhibited systems, the volume fraction of the hydrate slurry is low enough to allow for safe transportation of fluids during various operational conditions.
Lessons Learned from Optimising Sand Control and Management Strategies in a Low Permeability Sandstone Oil Field
Authors: Daramola Babalola , Alinnor Chidubem Martins 
Published: August 2021

Abstract
This paper presents the lessons learned from optimising the sand control and management strategies of an oil field (Field E) after multiple sanding events and well failures. It presents how the old sand control solution was selected, the failure root causes, and the remediation options considered. The new sand control method, and the performance of two re-drilled wells after two years of production are also presented.
Field E is a sandstone field with oil and gas-cap gas at initial conditions, and was initially developed with 5 production wells, 2 water injection wells, and 2 gas injection wells. The development wells were drilled from an offshore platform, and completed with stand-alone screens (SAS) in 2013. Oil production commenced in late 2013, and within three years, sand production was observed, and 4 of the 5 oil production wells had failed. The 4 wells were re-drilled in 2017, and the sand control strategy was changed from stand-alone screens to frac-packs.
Key lessons learned include completing sand strength studies pre-development, avoiding off-the-shelf sand control solutions, and completing sand control design studies based on service contractor capability, fines control, oil production rates, and sand control as key selection factors. Nearby wells should be shut in during infill drilling operations to avoid short circuits, drilling mud losses, completions damage, and well integrity failures.
It is recommended that the bean up procedures of wells with sanding events are changed to slow bean up to preserve well integrity, oil production, and cash revenues. The asset team should consider installing sliding sleeves or inflow control devices for zonal testing and to choke or close sand production zones if needed. The asset team should also consider installing a test pipeline and a test separator to allocate sand production volumes from each well, clean up new wells, sample the wells for water salinity measurements, and other benefits.
Cost-Effective Upgrades of Drilling Risers to 20,000 Psi Applications through Composite-Reinforced Steel Choke and Kill Lines
Authors: Persent Emmanuel , Grosjean Francois , Averbuch Daniel , Roguet Eléonore 
Published: August 2021

Abstract
Oil and Gas companies are considering drilling operations in the challenging high-pressure/high-temperature (HP/HT) environment, which requires new equipment to be qualified to 20,000 psi working pressure and 350°F maximum temperature.
In this study, IFP Energies Nouvelles (IFPEN) has considered the use of composite-reinforced steel Choke and Kill (C&K) lines for retrofitting an existing drilling riser equipped with 15,000 psi steel C&K lines to HP/HT applications. The feasibility of this upgrade solution has been validated through composite material testing and design studies.
The composite provides a 20,000 psi Choke and Kill line that is lighter than a 15,000 psi steel line for (almost) the same outer diameter (OD) while maintaining a nominal inner diameter (ID) of 4.5" for safer operations and ensuring a large safety margin on burst. These major advantages allow the C&K lines to be replaced without increasing the riser mass and with no other modification on the riser design. In particular, the expensive buoyancy modules can be kept in place.
Through combining the best features of steel and composite, this technology offers a cost-effective way to upgrade an existing drilling riser to 20,000 psi/350°F applications.
Digital Transformation and Automation of Flow Assurance Engineering Workflows Using Digital Field Twin
Authors: Patel Harshkumar , Cai Jianlin , Noiray Gautier , Bhowmik Subrata 
Published: August 2021

Abstract
Flow assurance is central to the design of a subsea production system and requires frequent interfacing with engineers from multiple disciplines. The objective of this paper is to demonstrate how cloud based digital field twin can be leveraged to automate subsea flow assurance engineering workflows and consequently, achieve efficient collaborations, faster and reliable designs, and reduced costs.
In this proposed workflow, engineers use a web application built on top of a cloud-based digital twin platform to perform flow assurance calculations and design analysis. The web based platform integrates multiphase flow simulators and other relevant engineering tools through python scripts. A user is only required to input design constraints and necessary basic information. The application acquires inter-disciplinary data (e.g. pipeline, layout, equipment, etc.) and automatically performs pre-processing, model setup, simulation, and results processing in the background and make results available to all the users at the front-end.
The digital flow assurance platform replaces traditional workflows requiring use of different standalone engineering software, and frequent exchange of information with other engineering teams in form of documents and spreadsheets. The proposed cloud-based workflow allows engineers to focus on technical analysis by eliminating several manual and repeating processes such as accessing different software, creating models, results extraction and formatting, etc. The ability to share results in form of auto-generated reports and formatted spreadsheets; minimizes human errors and promotes information exchange and transparency among project team members from different disciplines. The cloud based platform enables engineers to work on a same project from different geophysical locations and devices. Overall, this digital flow assurance workflow significantly improves engineering efficiency, save costs, and allows faster and reliable concept design and FEED (Front End Engineering Design).
The ideas widely discussed for flow assurance digitalization typically include use of data analytics and machine learning, virtual flow metering, real time data monitoring, predictive analytics, etc. This paper, however, presents novel practical idea to bring digital transformation to the way flow assurance engineers work and collaborate.
Legacy Field Upgrades - Production Control System Lessons Learnt
Authors: Moe Sigurd , Pham Dennis 
Published: August 2021

Abstract
This paper describes examples of functionality and equipment limitations encountered during the subsea field operational phase, and practical solutions to eliminate the limitations. It addresses changes and upgrades required to hydraulic, chemical and electric infrastructure. Modifications and upgrades, such as retrofit sensors, retrofit electric actuators, bypass connections and digital soutions are described. How a holistic obsolescence strategy can modernize the subsea functionality and let different generation systems coexist is further described.
Underwater Photogrammetry as an Environmental Assessment Tool to Monitor Coral Reefs and Artificial Structures
Authors: Vincent Mahamadaly , Isabel Urbina Bareto , Louis Fréchon , Romain Pinel , Rémi Garnier , Kenneth Deslarzes 
Published: August 2021

Abstract
Over the past decade, photogrammetry has grown considerably thanks to technical advances in digital cameras and computing performance. Popular in terrestrial applications with the development of UAV acquisition, photogrammetry provides access to accurate scene reconstruction, high-resolution measurements, and temporal comparisons with a wide range of geolocated and scaled 2D and 3D supports. Nowadays, photogrammetry represents a particular challenge in the underwater field such as environmental monitoring, marine construction, technical inspection, and archaeology. Our study aims to develop underwater acquisition protocols and new tools for marine resources surveys and management to understand the role of 3D characteristics in both coral reefs and artificial structures. Two specific protocols were designed and optimized to reconstruct from coral colonies to coral reefs and artificial structures (up to 500m²) with a mean resolution of 0.05cm/pixel. Here several quantitative descriptors based on 2D and 3D metrics (such as slope, length, surface, volume, rugosity) were calculated for morphological studies and temporal comparisons. The photogrammetric technique now offers higher quality and accuracy tools compared to traditional survey methods. These advantages make possible to access to new scientific surveys of underwater ecosystems and as environmental management tools may prove to be valuable for future.
Subsea Sulfate Removal and Low Salinity Plant Membrane Life Prediction for IOR and EOR
Authors: Haruna Ojonimi Samuel , Hegdal Torbjørn , Huang Xiaofei 
Published: August 2021

Abstract
Subsea water treatment technology for water injection provides a solution for an optimized water injection strategy on both green and brownfield applications. There are no space and weight constraints on the seabed, which enables simple, flexible, and reliable designs.
A full-scale sulfate removal and low salinity plant designed for seabed operation with minimum maintenance intervention has been in operation for ten months without any chemical cleans. This paper reviews the performance results used to predict the life and longevity of a subsea sulfate removal unit (SRU) for a field application in the North Sea.
The ability to reliably predict the potential risks and serving life of a system is crucial for the success of subsea processing equipment. Results from a test conducted over ten months evaluated the key design parameters such as SRU membrane permeate flux, recovery rate, and analyzed membrane fouling behavior during the test period. Lessons learned from the testing are incorporated into the model for more accurate and reliable membrane life prediction.
Field data was analyzed to extrapolate aging factors that are used in the membrane design projection software. The projection software simulated aging performance of the membrane over the membrane lifespan under subsea operation conditions, and the results were applied to determine operating philosophy, maintenance, and intervention interval for the subsea plant. Lessons learned from this field study were discussed and used as guidelines for the next phase full-scale design and practice.
This novelty field practice establishes a break-through step towards full implementation of subsea seawater treatment and injection for increased oil recovery (IOR) and enhanced oil recovery (EOR) purposes. This firsthand data helps the operators to optimize the operation on the seabed, which minimizes the downtime and demonstrates promising advantages of CAPEX and OPEX saving in the long run.
Next Generation High-Definition Geomagnetic Model for Wellbore Positioning, Incorporating New Crustal Magnetic Data
Authors: Nair Manoj , Chulliat Arnaud , Woods Adam , Alken Patrick , Meyer Brian , Poedjono Benny , Zachman Nicholas , Hernandez John 
Published: August 2021

Abstract
Magnetic wellbore positioning depends on an accurate representation of the Earth's magnetic field,where the borehole azimuth is inferred by comparing the magnetic field measured-whiledrilling (MWD) with a geomagnetic reference model. Therefore, model accuracy improvements reduce the position uncertainties. An improved high-resolution model describing the core, crustal and external components of the magnetic field is presented, and it is validated with anindependent set of measurements. Additionally, we benchmark it against other high-resolution geomagnetic models. The crustal part of the improved high-definition model is based on NOAA/NCEI's latest magnetic survey compilation "EMAG2v3" which includes over 50 millionnew observations in several parts of the world, including the Gulf of Mexico and Antarctica, and does not rely on any prior information from sea-floor geology, unlike earlier versions. The core field part of the model covers years 1900 through 2020 andis inferred from polar-orbiting satellite data as well as ground magnetic observatory data. The external field part is modelled to degree and order 1 for years 2000 through 2020. The new model has internal coefficients to spherical harmonic degree and order 790, resolving magnetic anomalies to approximately 51 km wavelength at the equator. In order to quantitatively assess its accuracy, the model was compared with independent shipborne, airborne and ground magnetic measurements. We find that the newmodel has comparable or smaller errors than the other models benchmarkedagainst it over the regions of comparisons. Additionally, we compare theimproved model against magnetic datacollected from MWD; the residual error lies well within the accepted industry error model, which may lead tofuture error model improvements.