bluuebunny/crossref_metadata_2025_split huggingface dataset:
Drilling Problems Forecast Based on Neural Network
Authors: Borozdin Sergey Olegovich , Dmitrievsky Anatoly Nikolaevich , Eremin Nikolai Alexandrovich , Arkhipov Alexey Igorevich , Sboev Alexander Georgievich , Chashchina-Semenova Olga Kimovna , Fitzner Leonid Konstantinovich 
Published: August 2021

Abstract
This paper poses and solves the problem of using artificial intelligence methods for processing big volumes of geodata from geological and technological measurement stations in order to identify and predict complications during well drilling. Big volumes of geodata from the stations of geological and technological measurements during drilling varied from units to tens of terabytes. Digital modernization of the life cycle of well construction using machine learning methods contributes to improving the efficiency of drilling oil and gas wells. The clustering of big volumes of geodata from various sources and types of sensors used to measure parameters during drilling has been carried out. In the process of creating, training and applying software components with artificial neural networks, the specified accuracy of calculations was achieved, hidden and non-obvious patterns were revealed in big volumes of geological, geophysical, technical and technological parameters. To predict the operational results of drilling wells, classification models were developed using artificial intelligence methods. The use of a high-performance computing cluster significantly reduced the time spent on assessing the probability of complications and predicting these probabilities for 7-10 minutes ahead. A hierarchical distributed data warehouse has been formed, containing real-time drilling data in WITSML format using the SQL server (Microsoft). The module for preprocessing and uploading geodata to the WITSML repository uses the Energistics Standards DevKit API and Energistic data objects to work with geodata in the WITSML format. Drilling problems forecast accuracy which has been reached with developed system may significantly reduce non-productive time spent on eliminating of stuck pipe, mud loss and oil and gas influx events.
Brazil Subsea Processing & Boosting Technologies Yard: More Than 20 Years of Lessons Learned
Authors: Roberto Marcello Augustus Ramos , Koelln Herbert Prince , De Rezende Rodrigo Iunes 
Published: August 2021

Abstract
Over the last 20 years Brazil has been the stage where subsea processing and boosting (P&B) technology has supported and pushed the offshore oil and gas production to overcome its challenges and maximize field production and recovery factor.
Subsea Oil-Water and Gas-Liquid Separation Systems, Multiphase Pumps, Electrical Submersible Pumps, Raw Water Injection Systems, and other innovative, enabler, optimizer or even disruptive technologies have been developing and applying in Brazil's fields to increase the NPV of projects and make feasible long tiebacks scenarios.
This paper will present a retrospective of the most significant P&B systems developed and deployed in Brazil's fields, their operational experience, lessons learned, the next generation under development to surpass Pre-Salt and brown fields challenges and some initiatives to maximize these technologies applications.
Recent Progress in Applying Advanced Computation Methods to Radar-Based Wave Measurements
Authors: Vinther Morten Loell , Eide Torbjørn , Paraschiv Aurelia , Bonvik-Stone Dickon 
Published: August 2021

Abstract
High quality environmental data are critical for any offshore activity relying on data insights to form appropriate planning and risk mitigation routines under challenging weather conditions. Such data are the most significant driver of future footprint reduction in offshore industries, in terms of costs savings, as well as operational safety and efficiency, enabled through ease of data access for all relevant stakeholders.
This paper describes recent advancements in methods used by a dual-footprint Pulse-Doppler radar to provide accurate and reliable ocean wave height measurements. Achieved improvements during low wind weather conditions are presented and compared to data collected from other sources such as buoys and acoustic doppler wave and current profiler (ADCP) or legacy.
The study is based on comparisons of recently developed algorithms applied to different data sets recorded at various sites, mostly covering calm weather conditions.
Dropped Polyester Mooring Line Qualification for Reuse
Authors: Gage Craig R , Liagre Pierre F , Heyl Caspar N , Del Vecchio Cesar 
Published: August 2021

The Perdido platform is a spar located in a water depth of 7,825 feet in the Alaminos Canyon Block 857in the Gulf of Mexico. The mooring system consists of nine mooring lines in three groups of three, spacedapproximately 120 degrees apart between each group. Each mooring line is composed of a platform chain,a multi-segment polyester rope including a 120 feet long test insert at the top, a ground chain, a pile chainand other associated connectors. The mooring lines are connected to suction piles. The Minimum BreakStrength for the Perdido polyester mooring line is 4,000 kips. Installation of the spar hull was completed inSeptember 2008 and the topsides was set in March 2009. The spar and its mooring system were originallydesigned for a twenty (20) year life.
On May 4, 2019, mooring line # 6 (ML6) was contacted by a marine vessel down line and was severed.Contact occurred along the polyester test insert. A recovery effort was planned, and the mooring line wasreplaced in early June. The original ML6 was recovered from the seafloor on June 4, 2019 as a part of thatcampaign and submitted to an initial inspection.
This paper is not intended to go into either the cause of the incident or the replacement of ML6 but willlook to the inspection of the recovered mooring line and explore its suitability for reuse. Initial inspection ofthe lines suggested minimal damage to the polyester rope segments and raised questions to the impacts of 10years of use. Testing was envisioned as a learning opportunity for the impact of service on polyester mooringand was reinforced by the potential cost savings that could be attained though reuse. A methodology wasdeveloped, supported by initial inspections and a suite of testing was performed. The results of these testsare presented in the following, along with a proposed process for assessing and considering reuse of a linefollowing a drop. Additionally, conclusions will be shared for the process, the results, and the potentialramifications for the industry.
Cash is King - Repurposing Marginal Assets to Reduce Floating LNG CAPEX
Authors: Tierling Kenneth Shane 
Published: August 2021

Objective / Scope
With renewable energy sources not currently able to move energy around the globe and forming small portions of the total global energy supply, it has fallen upon hydrocarbon sources to form the backbone of global energy movements. Hence, the recent energy demand decline, along with policy, have disproportionately impacted world-wide petroleum and LNG pricing. The impact on Floating LNG has been a heightened demand for capital efficiency, required to achieve final investment decision.
A business case specific means of reducing FLNG CAPEX, has been repurposing marginal assets. Starting with a breakdown of the cost components of an FLNG facility, this paper will provide examples of the inclusion of preexisting assets into FLNG projects to reduce capital cost. The paper will wrap up with other opportunities for cost savings, to stimulate thought.

Methods, Procedures, Process
Floating LNG (FLNG) technologies have been deployed to monetize mid-sized offshore gas reservoirs, avoiding constructing a sub-sea gas pipeline to a land-based LNG facility and export jetty. Containing the processing to an oceanic environment also reduces the impact on indigenous peoples as well as terrestrial flora and fauna. FLNG facilities also have the potential of serving multiple offshore fields over the life of the facility, thereby reducing the minimum size field that can be economically monetized.
Interest in FLNG continues, despite the current slump in energy prices, however these challenging times are refocusing efforts on reducing the capital cost of FLNG. This paper will explore recent capital cost trends in LNG, with a focus on floating LNG, examples of realized opportunities to reduce CAPEX, and further scope for reductions.

Results, Observations, Conclusions
The readers will take-away from this paper a deeper understanding of:
Recent trends in CAPEX for LNG, and specifically FLNG Where significant opportunities lie for cost reduction Examples of the reuse and repurposing of marginal assets to reduce cost of FLNG facilities Areas to be explored for future capital reduction

Novel / Additive Information
This paper pulls together disparate threads into a coherent whole, providing visualization of the trends and examples of realized opportunities.
Task Scheduling for Subsea Flexible Pipes Decommissioning
Authors: Bressan Robert da Silva , Artigas Danilo 
Published: August 2021

AbstractSubsea flexible pipelines removal is subject to order restrictions, mostly caused by crossings. It is proposed to create a computational algorithm to design an optimal order of vessel intervention over a field. A real field was studied, and, from it, the mathematical base model was created upon graph theory, with great correlation with the minimum feedback arc set problem. Vessel movements were discretized and reduced to removal, reposition, and cut, leading to a state search. A-star algorithm was implemented to guide the search for the solution. Then, the complete algorithm was built, tested in a minimal environment, and finally applied to the real instance. To improve performance, a beam search filtering was envisioned, using seven ranking functions. Constructed model is suspected to be NP-hard, by correlation to minimum feedback arc set problem, leading to a large space search. Instances containing under 100 crossings were solved optimally, without needing any assistance. After implementing the heuristics and beam search, solution time was lowered by about 20 times, demonstrating the effectiveness of the technique. Also, ranking functions for pipe repositioning based on crossing count led to better results than crossing density. For cutting, an approximation based on feedback arc set was used. GreedyFAS was employed and gave satisfactory results. Bigger instances containing around 3000 crossings could not be solved optimally in a reasonable time, even with the heuristics. Improvements in A-star estimation function and bound the solution branches might lead to an optimal solution for these larger instances. Model proposed simplifies the operational order decisions and helps build the scheduling of operations. As it is based on state search, other aspects in logistics, vessel capacities and steps in decommissioning processes may be added, adjusting the neighboring weights and branching, keeping the same core.
The Liza Field: From Discovery to Development
Authors: Austin Nicholas , Das Mita , Oyerinde Adedayo , Elkington Elizabeth 
Published: August 2021

AbstractIn May 2015, Liza-1 encountered more than 90 m (295 ft) of high-quality oil-bearing Upper Cretaceous deepwater sandstones. Immediately, the &gt;1 billion barrel Liza field began on its path from discovery to development.Following the Liza-1 discovery, ExxonMobil and the Stabroek Block co-venturers, Hess Guyana Exploration Limited and CNOOC Petroleum Guyana Limited, undertook a blockwide 3D seismic survey, the largest performed by ExxonMobil at that time, to better delineate the resource potential. Subsequent appraisal drilling built confidence in the performance and connectivity of the reservoir while providing calibration data to inform the development. The initial appraisal well was the "inverted-Y" Liza-2 drilled in early 2016, which comprised an original hole and a sidetrack. A comprehensive evaluation program was implemented with conventional coring of both the original hole and the sidetrack to provide reservoir calibration critical to field development. Furthermore, a production well test was performed on the Liza-2 sidetrack to build confidence in dynamic performance and connectivity assumptions. The Liza-3 appraisal was then drilled down dip of the Liza-1 and −2 to confirm static connectivity across the field.A scenario modeling and simulation approach was implemented at Liza to capture the full range of plausible realizations that could represent the field. The scenarios were measured against the incoming data (Liza-2 and Liza-3) when acquired, and scenarios with greater alignment to the data continued to be pursued while others were moved to a much lower probability of occurrence. This multi-scenario approach was utilized to develop an integrated reservoir model that allowed for depletion plan optimization across a range of subsurface scenarios within flow assurance constraints, ultimately supporting the final investment decision (FID) for the Liza Phase 1 project in 2017, just 25 months after the Liza-1 discovery.Following FID, advanced, proprietary Full Wavefield Inversion seismic reprocessing and high resolution 4D baseline seismic acquisition and processing have been utilized to enable continued optimization. The path from discovery to development culminated in December 2019 with the commencement of production from Liza Phase 1 less than 5 years after the first deepwater oil discovery in Guyana.
Center of Excellence: Leveraging Data to Reduce Incidents on Offshore Oil and Gas Assets
Authors: Bayon Le Ronan , Boyd Leah 
Published: August 2021

Abstract
This paper presents a novel approach to finding solutions to unsafe work practices in oil and gas environments—from manufacturing facilities to offshore platforms. The ‘Center of Excellence’ approach is a stepwise process for classifying safety events and harnessing data to reduce incidents during offshore oil and gas E&P activities.
The approach includes identifying focus topics related to unsafe practices, forming cross-functional teams with significant field or impacted personnel participation, developing and implementing measures, utilizing the hierarchy of controls to mitigate the issue, and raising company-wide awareness through training and targeted information campaigns.
The Center of Excellence process gives top priority to those activities in order to reduce the highest severity and most frequent safety incidents. The teams are then able to more clearly identify feasible solutions, including engineering controls, training, campaigns, and procedures to contain the hazards.
The active engagement and involvement of frontline employees who either work in the field or on the factory floor is critical to understand the daily hazards of their work activities and the success of the Center of Excellence approach. With these employees acting as a champion of the developed solution, other workers are more likely to accept and adopt it in their daily routine.
This paper reviews practical examples of how the Center of Excellence approach has led to safer practices in the workplace. Examples include improved safety measures for using tightening tools, which led to more than 50% reduction in hand injuries and other safety incidents. A recent example of using the approach to develop safer practices during manual handling of loads (MHL) is also presented. The examples highlight the benefits of bringing multifaceted teams and multiple industry-accepted safety concepts together to resolve common work safety challenges, which can serve as a blueprint for oil and gas companies to reduce incidents across their enterprise.
Protective Barrier Wall Response to Sequential Blast and Fire Events
Authors: Smith Hunter 
Published: August 2021

Abstract
Blast and fire-resistant barrier walls are often required on offshore platforms to protect from accidental events. A wall structure designed for a probabilistic explosion event typically relies on inelastic response and plastic deformation to maintain a lightweight, efficient design. Design guides for such structures do not explicitly address how to account for the effects of interaction of blast and fire loading on structural performance and design acceptance criteria. If a wall assembly is required to provide rated fire and gas protection after an explosion event, it is generally assumed that structural integrity is maintained due to temperature increase limits (140°C) from the H-60/120 rated fire protection on the wall. This paper investigates the validity of this assumption for a typical offshore barrier wall designed to undergo permanent deformation during an initial blast event.
The study was performed utilizing non-linear dynamic finite element analysis (FEA). FEA allows for design iteration, structural assessment, and validation against extreme load scenarios when testing of full-scale assembly may not be feasible. A typical wall structure was first analyzed for blast loading by non-linear dynamic structural analysis. Thermal loading from a subsequent hydrocarbon fire was then applied to observe the structural response in the post-blast damaged condition. Based on the rated temperature range, the resulting thermal expansion in the wall panels induces large stresses at the interface between wall panels and supporting steel. Non-linear FEA confirmed that yielding occurs which may increase existing plastic strains beyond design limits at locations of high stress concentration. Therefore, it is prudent to consider thermal performance in the design process, especially regarding connections and penetrations.
Buzios Presalt Wells: Delivering Intelligent Completion In Ultra-Deepwater Carbonate Reservoirs
Authors: Schnitzler Eduardo , Gonçalez Luciano Ferreira , Roman Roger Savoldi , Marques Marcello , Gutterres Fábio Rosas , da Silva Manoel Feliciano , Castilho Carlos Alexandre Belo 
Published: August 2021

Abstract
This paper describes the challenges faced on the deployment of intelligent well completion (IWC) systems in some of the wells built in Buzios field, mostly related to heavy fluid losses that occurred during the well construction. It also presents the solutions used to overcome them. This kind of event affects not only drilling and casing cementing operations, but may also prevent a safe and efficient installation of the completion system as initially designed.
The IWC design typically used in Brazilian pre-salt areas comprises cased hole wells. Perforation operations must be performed before installing the integral completion system, as it does not include a separation between upper and lower completion. Therefore, the reservoir remains communicated to the wellbore during the whole completion installation process, frequently requiring prior fluid loss control as to allow safe deployment. Rock characteristics found in this field make it difficult to effectively control losses in some of the wells, requiring the use of different well construction practices that led to the development of some new well designs.
The well engineering team developed a new well concept, where a separated lower completion system is installed in open hole, delivering temporary reservoir isolation. This new well architecture not only delivers reduced drilling and completion duration and costs, but also provides the IWC features in wells with major fluid losses. This is possible by the use of multiple managed pressure drilling (MPD) techniques when required, which were considered since the initial design phase. Safe and effective construction of some wells in pre-salt fields was considered not feasible before the adoption of MPD solutions, both for drilling and completions.
Other important aspects considered on the new well design are the large thickness and high productivity of Buzios field reservoirs, as well as the need of some flexibility to deal with uncertainties. Finally, the new completion project was also designed to improve performance and safety on future challenging heavy workover interventions. The well construction area has gradually obtained improved performance in Buzios field with the adoption of the new practices and well design presented in this paper.
The new solutions developed for Buzios field have set a new drilling and completion philosophy for pre-salt wells, setting the grounds for future projects. The improved performance is essential to keep these deepwater projects competitive, especially in challenging oil price scenarios. One of the groundbreaking solutions used is the possibility of installing the lower completion using managed pressure drilling techniques.
Flexible Pipes Subjected to SCC CO2: Review and Means to Increase Reliability on Service Life Applied to Brazilian Pre-Salt Fields
Authors: Brandao Mauricio , Pires Fabio , Poloponsky Ingrid , Santos Fabio , Lopes Diogo 
Published: August 2021

AbstractFlexible Pipes were widely used in Brazil offshore developments and the challenge on overcoming increasing water depths, high pressures and fluids with high contaminants was always present. In 2017 a new failure mode, called SCC CO2 was disclosed bringing such disruption in the use of this equipment since, at that time, the conditions observed in Brazilian Pre salt were like the "perfect storm" for the failure mode to happen. It had high concentrations of CO2, therefore high permeation in the anulus, high stresses and the possibility to have anulus flooded as result of an outer sheath breach or even due to permeated water. These were the triple conditions needed to have the failure, considering that all metallic material used in the pipe were subjected to this phenomenon.Since the discovery was made, several test campaigns to better understand and replicate the phenomena started. They covered pipe retrieved from field dissection, several small-scale materials testing, and fracture mechanics to create reliable crack propagation calculations. There were 3 mains focus areas; to understand how to deal with the installed fleet, to define the conditions in which a crack would appear and define, using fracture mechanics, how long a crack would take to break the wire. In other words, it was intended to define what is the remaining service life.As a result of this investigation some initial beliefs like that all materials were subjected to the phenomena and that a solution was far away were somehow reduced and reshaped. There was also the initiative to embark on technology for detection of the anulus condition, mainly to define if it is flooded or not. Some ROV inspection means were added to the endfitting and some sensors were added to the interconnected pipe sections that allow conditioning monitoring or inspection from the floating unit, not using a ROV.This paper will cover the improvements done since the disclosure of the phenomena in 2017, reviewing what is known about it so far, what is still to be discovered and how the results achieved to date can contribute for a more reliable and longer service life for the flexible pipes to be applied in a rich CO2 environment.