bluuebunny/crossref_metadata_2025_split huggingface dataset:
Buzios: The Largest Ultra-Deepwater Oilfield to Date
Authors: de Oliveira Jose Olavo de Andrada Ignacio , Tavares Pedro Lemos , da Silva Victor Costa , Lima Ivan Noville Rocha Correa , Britto João Francisco Fleck Heck , Hernalsteens Thierry , Kahn Marcio 
Published: August 2021

Abstract
The purpose of this paper is to present a general overview of the Buzios field development plan, projects’ features, and main achievements so far.
The development plan adopted a strategy to pursue the balance between acceleration and cash flow optimization, to maximize the return on the huge investment on the block acquisition, and the risk management related to developing several Greenfield Projects simultaneously. To reduce reservoir uncertainties, a comprehensive data acquisition plan was crafted and implemented considering: (a) seismic acquisition, (b) drilling, logging and testing several exploratory and appraisal wells, (c) massive rock and fluid data sampling along the reservoirs, (d) execution of one Extended Well Test and three Early Production Systems.
Additionally, the basic design of wells, subsea systems and Floating Production Storage and Offloading ("FPSO") provided flexibility to cover remaining uncertainties yet present in the Transfer of Rights ("ToR") scope, which allows up to 3,150 billion barrels of oil equivalent ("boe") to be produced. This led to technological challenges that needed to be addressed during project planning. We believe that the innovative solutions applied enhanced currently available technologies and delivered an important legacy to the offshore oil and gas industry.
Finally, the results obtained so far, with the ramp-up of Buzios projects 1, 2, 3, and 4 provide evidence of the successful adopted strategy and reinforce the decision of deployment of a fifth FPSO under the scope of the ToR contract. The strong results of the asset led to the acquisition of 90% of the Transfer of Rights Surplus ("ToR+"), together with CNOOC Petroleum Brasil Ltda. (5%) and CNODC Brasil Petróleo e Gás Ltda. (5%), which now paves the way for a second wave of development, including the deployment of up to seven additional FPSOs.
Hybrid Conductor-Supported Tripod Platform: Brownfield Design Perspective to Unlock Production Capacity
Authors: Ozkul Selma Nur , Huang Wen-Xing , Taxy Stephane 
Published: August 2021

Objectives/Scope
Oil and gas companies have shifted their investment priorities to low CAPEX brownfield projects in response to historically low oil and gas prices. One approach is to increase the production by drilling new wells and tying them back to existing tripods. However, existing tripods have limited as-built design data and are usually near the allowable structural capacity limits. This study introduces a novel concept of the "hybrid conductor-supported tripod" to support the new wellheads. This approach minimizes the need to modify the existing tripods.

Methods, Procedures, Process
The hybrid conductor-supported tripod utilizes the new well conductors to support the wellheads, extends to the existing tripod topside to support the production facilities, and resists lateral loads from the new wellheads. Such hybrid conductor-supported tripod takes advantage of the axial compression capacities of the new conductors while its lateral resistance is provided by integrating only the new topside with the existing tripod's topside. Thus, the underwater structural modifications of the existing tripods are minimized.

Results, Observations, Conclusions
Design and construction challenges commonly encountered during the design phases of brownfield projects include: 1) lack of tripod jacket and foundation as-built data, 2) need for bracing the new conductors to the existing jacket underwater due to buckling and vortex issues, 3) as-built conditions of the tripods are already near their structural capacities. The design and construction issues experienced in low budget and tight schedule brownfield projects are alleviated with the use of a hybrid conductor-supported tripod. A parametric study was conducted to identify the minimum conductor pipe diameters needed for hybrid conductor-supported tripods at various shallow water depths in benign environmental conditions. The in-place conditions of several existing tripods were investigated before and after the hybrid conductor-supported tripods were integrated with the existing tripods. Using hybrid conductor-supported tripods enable production increase on existing facilities with minimal CAPEX investment. This is accomplished by: 1) utilizing existing tripods to increase production, 2) mitigating the need for as-built data, especially underwater jacket data, 3) eliminating additional axial loads on the existing tripods, 4) implementing minimum deck extensions on the existing tripods.

Novel/Additive Information
The hybrid conductor-supported tripods provide the structural expansion need for the new wellhead facilities while keeping the existing tripods in their as-built conditions. Reducing the need for the current condition and the exact as-built underwater information of the existing tripods will accelerate the execution of the low budget and tight schedule production increase brownfield projects.
Validation of Spectral Fatigue Assessment of a West-Africa FPSO Using Full-Scale Measurements
Authors: Andoniu Alexandru , de Lauzon Jérôme , Hageman Remco , Aalberts Pieter , L'Hostis Didier , Ledoux Alain 
Published: August 2021

AbstractIn order to ensure structural integrity and safe operations, fatigue assessment of structural details is a key aspect of design and verification procedures for FPSOs. Spectral fatigue analysis is widely used in the offshore industry to assess damage induced by wave loading. However, the actual fatigue accumulation endured by units in operations usually differs from predictions due to the assumptions made at the design stage. One of the sources of uncertainty is the representation of the encountered sea states. The objective of this paper is to use in-situ measurements as a reference for evaluating the accuracy of spectral fatigue analysis and to investigate the influence of wave energy description on the fatigue assessment.Structural health monitoring systems have been increasingly used in the last decade in the offshore industry as they constitute a valuable source of information regarding the actual operating conditions, structural response, or encountered environmental conditions. This data can be used to update fatigue assessment in order to determine the remaining service life, understand how the structure is aging, or support for decision making regarding inspections, maintenance, or lifetime extension. The work presented is based on such information gathered during a measurement campaign performed on a spread-moored FPSO in West Africa. Measured strain time histories at several locations on the hull have been used to derive the actual fatigue damage endured by the unit. These damages are compared to the ones determined from spectral fatigue analysis using stress transfer functions obtained from frequency domain hydro-structure computations.Multiple analyses have been performed to evaluate the impact of different sources of statistical wave data and wave energy descriptions on the fatigue assessment. The wave conditions used originate from wave buoy measurements and hindcast data. Overall, the good agreement between full-scale measurements and calculations confirms the suitability of spectral methods for determining fatigue damage. When incomplete information is available, which is often true in the case of wave statistics, assumptions have to be made regarding parameters such as spectrum shape or wave spreading. However, using the full description of wave energy spectra, if available, can be a way of reducing uncertainties and removing unnecessary assumptions in such analysis. The results of this work show how fatigue assessment can be improved by gaining insight into the different sources of uncertainty, notably the sea state representation. With increasing focus on digital solutions, these results show realistic potential for virtual hull monitoring solutions based on accurate numerical models and realistic representation of wave conditions.
Buzios Drainage Strategy: A Combination Of Reservoir Characterization, Risks Mitigation And Unique Contract Features
Authors: Silva Victor , Moliterno Ana , Araujo Carlos Henrique , Pimentel Francis , Melo Jose Ronaldo , Falcao Claudio , Pessoa Thiago 
Published: August 2021

Abstract
Petrobras acquired the right to produce 3.058 billion boe under the Transfer of Rights (ToR) in Buzios field, which still has a recoverable surplus, recently auctioned by the Brazilian Petroleum Regulatory Agency. Properly planning the production development of a supergiant field and under two tax regimes, requires a large multidisciplinary effort of data acquisition, characterization and modelling.
Located in the Santos Basin Pre-Salt Pole, the Buzios field is a deep-water supergiant that has a large thickness of carbonate reservoirs, with significant areal and vertical variation. The presence of faults, fractures, karsts and other diagenetic processes adds complexity to the field, which motivated the development and implantation of industry innovations to enable its development. The presence of high levels of CO2 and H2S in the reservoir fluid, the risk of inorganic scaling and asphaltene deposition and risks of early fluid channeling and low sweep efficiency due to the aforementioned geological complexities are challenges that need to be addressed.
One of these challenges is to ensure a better seismic data for the reservoir characterization. The 3D seismic data from a streamer acquisition did not have sufficient quality for this. The geological complexity of the field, the great reservoir depth and mainly the very irregular topography of the overlying evaporitic sequence indicated the need for rich azimuth seismic data. This led to the world's largest ultra-deep water seismic survey using Ocean Bottom Nodes (OBN) technology.
This paper will address the static and dynamic data acquisition from the wells and the Early Productions Systems (EPS), as well as the challenges that arose and were faced by Petrobras through technology and innovation, and the complexity of the reservoir dynamic modelling. Furthermore, the OBN seismic acquisition in Buzios will be discussed in more detail, as well as the frontier that this acquisition opens to the development of the field.
The Autonomous Inflow Control Valve Design and Evaluation Criteria Along with Well Performance Review for Multiple Installations Across the Globe
Authors: Kalyani Tejas , Aakre Haavard , Mathiesen Vidar 
Published: August 2021

Abstract
Many wells across the globe have been installed with Inflow Control Device (ICD) technology to balance the production across the production interval, addressing some of the challenges associated with horizontal and deviated wells. Nevertheless, ICDs have limitations with restricting unwanted fluids upon breakthrough. Autonomous Inflow Control Valve (AICV) technology functions similar to an ICD initially (i.e., balancing flux across the length of horizontal wells, effectively delaying breakthrough) but provides the additional benefit of shutting off the flow of unwanted fluids upon breakthrough. This paper will present comprehensive AICV completion design workflow along with multiple case histories highlighting the reservoir management benefits of the AICV technology in mitigating un-wanted inflow of water and gas and delivering improved oil production and recovery.
Like other AICDs (Autonomous Inflow Control Device), AICV can differentiate the fluid flowing through it via fluid properties such as viscosity and density at reservoir conditions. However, AICV's performance is much more effective due to its advanced design which provides further benefits using both Hagen-Poiseuille's and Bernoulli's principles. AICV technology is based on the difference in the pressure drop in a laminar flow element (LFE) compared to a turbulent flow element (TFE) and has a capability to shut-off the main flow autonomously when an unwanted fluid such as water or gas breakthrough occurs. Thus, reduces well water cut (WC) and/or gas-oil ratio (GOR) significantly. Rigorous single-phase and multiphase flow-loop tests have been conducted covering a wide range of fluid properties to characterize the AICVs flow performance. Extensive plugging testing and accelerated erosion tests have also been conducted. This paper presents some of these flow performance analysis and testing results. Furthermore, the paper will also discuss in detail a reservoir-centric AICV completion modelling and design workflow.
Finally, this papers also discuss in detail AICV well performance installed in a light oil as well as in heavy oil reservoirs and how operators achieved higher OPEX saving as well as higher ultimate recovery (UR) from the wells due to prolonged as well as significant reduction in water cut and/or lower GOR.
The AICV design methodology and performance evaluation analysis is presented through several case studies. The analysis takes into account the whole cycle: from flow loop testing to characterization, reservoir modelling, optimized AICV completion design and post-installation well performance to evaluate the AICV technology benefits.
Aerial Robotic Systems Drones for Contact-Based Ultrasonic Wall Thickness UT Measurements at Height
Authors: Dahlstrom Robert L. 
Published: August 2021

Abstract
The use of aerial robotic systems that physically contact oil and gas structural assets to obtain measurement data in offshore and marine environments carries unique challenges and operational variables. The objectives of this paper are to demonstrate, with examples, how these aerial robotic systems afford safer, cheaper, and better nondestructive testing (NDT) measurement collection methodology and allow more robust insight into assets conditions than the slower, less safe, and more expensive manual method.
To take NDT measurements such as Ultrasonic Wall Thickness (UT) Measurements at height, currently one needs to utilize a lift, ladders or other solutions to reach areas on certain assets. This can be both dangerous, due to the possibility of falls, and time consuming. Utilizing an aerial robotics platform for contact based (not visual) NDT measurements such as Ultrasonic Thickness (UT) allows workers to remain safely on the ground. Drones, with robotic arms, have the potential to improve inspection, testing and data collection. This paper explores an aerial robotic system that flies up to a structure with a metal sub-straight, then under full autonomous software control, touches a UT measurement probe to the target and records the measurement data compliant with American Petrolium Institute (API) and other standards.
The use of aerial robotics systems for NDT is still a new and novel application utilizing existing technologies such as electronic measurement readers, drones, etc. with a system of complex integrations that allows for a better application of science. Aerial Robotic NDT systems have the potential to improve the inspection, testing and data collection aspects of coated and uncoated assets, in part, by making the NDT measurement process easier and safer thus allowing for more frequent measurements and/or a larger quantity of measurement samples.
When possible, working at heights should be eliminated as part the hierarchy of fall protection stipulated by both OSHA and ANSI. For this reason alone, the use of aerial robotic systems is important now and in the immediate future Oil & Gas infrastructure, including Offshore. This paper intends to provide readers an awareness of this new technology as well as provide information about its efficacy, limitations and operational requirements.
The World Deepest Electrically Heat-Traced Flowline
Authors: Hurault de Ligny Florent , Cuau Thomas , Immel Stephen 
Published: August 2021

Abstract
Electrical heat tracing technologies for flowline applications have been in development phase for some time. Yet in recent years, the efforts to deploy this technology on real life applications have intensified, leading to several projects in the industry simultaneously adopting this solution. As often seen with technology development, implementing the serial number 1 of a technology requires one project with favorable conditions and parameters, but also the stakeholders willingness to face the challenge associated to being first, and having to cross the final gap between the qualification program and this real life application. This paper presents how a specific project met all the conditions to be the first to select and implement a deepwater EHTF® (Electrically Heat-Traced Flowline) solution.
This paper presents the Project from the concept selection phase, to the execution and offshore installation of the final product. This provides an overview of why this technology was selected, and how the Project was executed, with a focus on the main challenges encountered and the associated solutions.
The concept selection phase for this two-well development consisted of comparing subsea tie-in architectures to tieback architectures using one or several new risers. The EHTF® emerged as the highest value solution, offering the best compromise between technical, economical, risk and schedule criterion, as it enabled single line tieback, while significantly reducing the operational risks associated to such architecture. A FEED was launched to further define and accurately estimate the concept, in order to reach FID. Close collaboration between the Operator and the Contractor at every step of the process allowed the solution to be selected and developed in a fast track manner while enabling the Contractor to provide an optimized, tailor-made solution.
The project execution involved many work sites, including the Vigra spoolbase in Norway for EHTF® fabrication, as well as the Seven Vega, which was a brand-new addition to the pipelay vessels fleet at the time of the Project. Many challenges arose during the project execution, as the qualification program was being completed, but adequate solutions were developed, allowing the Project to continue its course.
Obviously, there were many lessons learned along the way, which will feed into further product development plans, in order to improve its technical performance and competitivity. Heat tracing solutions offer great opportunities for single line long tieback development which often come with elevated operating risk profile due to complex wax and hydrate management. Enhanced thermal performance of resistive heating systems makes it possible to operate with low power consumption, which is a key in today's world of energetic efficiency.
Introducing an Innovative Perfluoroelastomer Cross Linking Technology: Achieving Superior Chemical Resistance and Thermal Stability
Authors: Alvarez Jimmy , Bish Christopher J. , Rodriguez Andres 
Published: August 2021

Objectives/Scope
Perfluoroelastomers are a class of synthetic elastomers that provide extraordinary resistance to oils, chemicals, and heat. The outstanding thermal stability and excellent corrosion resistance of these materials is dependent on the perfluorinated polymer chain, and the absence of unsaturation. However, the cross-link which is necessary to impart elastomeric properties must also share those stability traits. Unfortunately, designing a suitably inert cross-link is technically difficult to achieve and consequently it has not been possible to provide the ultimate in perfluoroelastomer properties. This paper is a review of the cross-linking chemistry of perfluoroelastomers and highlight a novel and patented cross-link which combines broad chemical resistance and superior thermal stability.

Methods, Procedures, Process
Several perfluoroelastomers formulations were selected and tested using representative standardized test methods to quantify their performance. The testing included compression set resistance, swell in fluids, and compression stress relaxation. In addition to the testing, chemistry of the cross-link was explained and how it is related to the observed performance results. The novel cross-link, triazole, was identified as an improvement versus existing cross-links.

Results, Observations, Conclusions
The testing demonstrated that previously available perfluoroelastomer cross-link chemistries display compromises in overall performance. For example, it had not been possible to achieve high thermal stability combined with resistance to almost all fluids. Overall, the data generated showed that the newly developed triazole cross-link system broadens the performance envelope of perfluoroelastomers and helps to alleviate the compromises of the past.

Novel/Additive Information
The newly discovered triazole cross-link with enhanced chemical and thermal stability enables broader use of perfluoroelastomers in extreme applications.
Significant Reduction of Well System Fatigue by Use of Reactive Flex Joint with Integrated Monitoring System
Authors: Sønåsen Knut Olav , Moe Per Thomas , Hansen Morten , Fjeldstad Dag André , Gustad Halvor , Sadeghi Alireza , Hilley Alexander , Bjørset Arve 
Published: August 2021

Abstract
Operators working on shallow and mid-water depths in rough seas are focusing on reducing fatigue in the upper part of well systems during drilling operations. Fatigue is caused by cyclic bending moments due to wave induced riser and vessel motions. The combined use of a Reactive Flex-Joint (RFJ) and the Well Access Management System (WAMS) has demonstrated significantly reduced fatigue exposure through a reduction in loads, reporting of real-time status and rig positioning advice.
The RFJ is a mechanism mounted on a standard flex joint for easy installation on drilling rigs. It uses a nitrogen gas spring to reverse the flex joint bending moment. The generated opposing moment increases with an increasing angle of the lower flex joint. This significantly reduces the cyclic bending moments in the lower part of the Blow Out Preventer (BOP) and wellhead (WH) system. WAMS is an advanced monitoring system that may be operated as a fully integrated part of the RFJ design. Sensors provide real-time data for flex joint angle, BOP inclination, wellhead- and riser bending moments. The data is used to assess incurring fatigue damage in real-time and for reporting fatigue status after operations.
Two RFJ systems have been in continuous use on two separate rigs during 2020. The RFJ system and WAMS are field-proven and have demonstrated their efficiency in challenging operations in the Barents Sea and the North Sea. The RFJ has been well received in the market due to one-time installation, safe use, significant reduction in wellhead loads, and low operating expenses (OPEX).
Data obtained from the operations have been carefully analyzed and show that the RFJ reduces cyclic loads from 50 to 80% resulting in 30 to as much as 1000 times extended fatigue life of the wellhead. The RFJ efficiency depends on the settings of the system and operational conditions.