bluuebunny/crossref_metadata_2025_split huggingface dataset:
Springs® Design Optimized By Seawater Quality. Laboratory Pilot Tests
Authors: Pedenaud Pierre , Rondon Marianna , Lesage Nicolas , Tournis Eric , Giolo Riccardo , Skivington Graeme 
Published: August 2021

Abstract
A new seawater laboratory pilot has been installed in order to evaluate the impact of the seawater quality on the performance of nanofiltration membranes and filters. The test program implemented was designed to produce the data required to optimize the design and operating parameters of a subsea sulfate removal plant, particularly with respect to the technology developed by Total, Saipem and Veolia, co-owners of the development. The equipment qualification plan is approaching completion with the development of subsea barrier-fluidless pumps, all-electric control systems, high-cycling valves operated by electric actuators and subsea water analyzers. This presented pilot laboratory study completes this plan.
Nanofiltration membranes are commonly used to remove the sulfates found in seawater before the water is injected into wells. The principal advantages of relocating this equipment from topside to subsea are better reservoir sweep control, a substantial subsea water injection network reduction and savings on space and weight on the topsides deck. The move to subsea offers the opportunity to simplify the process due to improved deep water quality. This was previously demonstrated through a subsea test campaign. This new pilot study provides data both on the performance of a plant operating with different feed water quality and on the success of operating changes to further optimize the plant performance.
The pilot has been installed at the Palavas-les-Flots site in France. Raw water collected from the basin was mixed with ultra-filtered water in order to calibrate the feed water quality. The pilot includes a two stage nanofiltration configuration and single stage nanofiltration unit. The two stage configuration was used to produce data for operation across an array of feed water quality and plant operating conditions. The single stage unit was used to produce data on membrane fouling over a long operating duration. Results from these tests and discussion on how this data relates to subsea plant performance shall be presented.
This innovative approach enables a wide range of subsea water quality to be simulated and tested against different process configurations of the subsea unit. Indeed, for each industrial subsea application, the raw seawater quality is dependent on both the region and the depth of the seawater inlet. With this experimental data acquisition campaign and understanding of the seawater quality at inlet, the system design can be tailor-made for each future application case.
Aqueous Degradable Polyurethane Elastomers for Oil & Gas Applications
Authors: Burdzy Matthew Peter 
Published: August 2021

Abstract
A new class of patent pending aqueous degradable polyurethane elastomers have been developed that can be used in oil & gas exploration, drilling, completion and production where a degradable part is needed to provide a useful service life then quickly degrade when exposed to heat and water. This polyurethane technology eliminates the need for costly secondary operations such as milling, drilling or removing tools in downhole applications saving time and reducing cost. The degradable polyurethane is a low viscosity two-part heat cured elastomer that is easy to mold using low cost hot cast tooling techniques. The novel liquid polyurethane prepolymer can be formed into films, seals, sealing elements, tools, complex geometries or other aqueous degradable elastomeric components. The polymer is a tough tear resistant high strength elastomer with a tensile strength exceeding 5000 psi, elongation over 500%, and a 70% compression modulus greater than 13,000 psi. When integrated as a sealing element in a degradable hydraulic fracturing plug, the polyurethane is designed to be pumped down-hole, set and seal then degrade once the operation is complete. Once placed into service, the useful operating lifetime of this polyurethane chemistry is more than six hours when immersed in aqueous fluids at 80°C (176°F) (i.e. water or 3% potassium chloride). The elastomer can be compressed over 70% during its service-life providing a stable set of mechanical properties during use. The elastomer beings to fracture within two days and quickly degrades at 80°C (176°F) providing consistent and reliable results. Approximately 70% is completely water soluble while the remaining 30% fractures into small particles that can be easily removed or remain in the well. This paper reviews the development of the technology, applications, mechanical properties, service life, degradation profile and product life cycle.
Surface Treatment Strategies for Mitigating Gas Hydrate & Asphaltene Formation, Growth, and Deposition in Flowloops
Authors: Pickarts Marshall A , Delgado-Linares Jose , Brown Erika , Veedu Vinod , Koh Carolyn A. 
Published: August 2021

Abstract
Numerous solids including gas hydrates, waxes, and asphaltenes have the potential to form in the production lines of gas and oil fields. This creates a highly non-ideal scenario as the accumulation of said species leads to flow assurance issues, especially with long-term processes like deposition. Since an ever-increasing amount of material is deposited in place at the pipe surface, production stoppage or active mitigation efforts become inevitable. The latter production issues result in increased safety risks and operational expenditures. Therefore, a cost-effective, passive deposition mitigation technology, such as a pipeline coating or surface treatment is especially appealing. The ability to address multiple pipeline flow assurance issues simultaneously without actively disrupting production would represent a dramatic step forward in this area.
This study is part of a long-term ongoing effort that evaluates the performance and application of an omniphobic surface treatment for solids deposition prevention in industrially relevant systems. In particular, this specific work concentrates on the efficacy and robustness of the treatment under fully flowing conditions. The apparatuses utilized for this include two flowloops: a lab-scale, high-pressure flowloop for gas hydrate and surface treatment durability studies, and a bench-scale, atmospheric pressure loop for crude oil and asphaltene experiments.
Film growth in high-pressure flowloop tests corroborated previous reports of delayed gas hydrate nucleation observed in rocking cells. Without the aid of the memory effect, treated oil-dominated experiments never experienced hydrate formation, spending upwards of a week in the hydrate stability zone (at the subcooled/fluid test conditions). Subsequent tests which utilized the memory effect then revealed that the hydrate formation rate reduced in the presence of the surface treatment compared to a bare stainless-steel surface. This testing was part of a larger set of trials conducted in the flowloop, which lasted about one year. The surface treatment durability under flowing conditions was evaluated during this time. Even after experiencing ∼4000 operating hours and 2 full pressure cycles, no evidence of delamination or damage was detected. Finally, as part of an extension to previous work, corroded surface asphaltene deposition experiments were performed in a bench-top flowloop. Treated experiments displayed an order of magnitude reduction in both total oil (all fractions of crude oil) and asphaltene fraction deposited.
Optimization of Control Line Encapsulation Based on Numerical Simulations of Shock and Vibration
Authors: Nardi Luiz Fernando Bermero , Sias Daniel Fraga , Abreu Leonardo Teixeira Fernandes , Guimarães Mariana Silva , Da Silva Manoel Feliciano , Eduardo Thiago Handerson Torres 
Published: August 2021

Abstract
Control line integrity is fundamental to ensure operability of intelligent completion systems. Damage to control lines can normally occur during string deployment (by shock), or during productive life (by vibration-related fatigue). This work aimed to investigate how encapsulation will affect control line survivability throughout their entire life cycle.
Numerical simulations were carried out using geometrical arrangements of control lines typically found in completion valves and tubings. For installation loads, lines were submitted to shock simulations, both inside and outside of protection clamps. The role of flatpack material was studied, as to which kind of material would better absorb impact energy. For productive life loads, the flow-induced vibration was taken into account for high-rate injector wells. Vibration loads were based on force results obtained by Computational Fluid Dynamics (CFD). Structural Finite Element Analysis (FEA) was performed to obtain local tensions to estimate productive life of lines.
Technologies for Advancing Offshore Enhanced Oil Recovery Capabilities
Authors: Melchert Elena Subia , Long Roy Clayton 
Published: August 2021

Abstract
Last year the Department of Energy (DOE) presented a description of the expansion of its research portfolio from one focused on research primarily for onshore applications to one that includes projects specifically for offshore application. That paper (OTC - 30469-MS) also included key research results for the portfolio beginning with projects initiated in 2007. This paper follows on that theme and presents an overview of the Department's current research portfolio focusing on recent-past learnings, current learnings, and research gaps identified from the projects in the current research portfolio 2017-2023.
Discussion includes projects that are sponsored by the Department as part of its public-private partnerships with principal investigators from industry and academia, and those projects sponsored by the Department at its National Laboratories. The discussion also includes an overview of activities and projects jointly pursued by DOE and the Department of the Interior's Bureau of Safety and Environmental Enforcement (BSEE) pursuant to the July 2020 Memorandum of Collaboration signed by both agencies.
Major insights presented in this paper focus on innovative mid-Technology Readiness Level (mid-TRL) technologies that will enable cost-effective enhanced oil recovery in deepwater and ultra-deepwater including insights for cement and wellbore integrity, flow assurance, life extension of offshore platforms and risers, sensors and telecommunications, early kick detection, chemical delivery, data analytics involving big data sets and modeling, and advanced sensors for EOR operations.
Many of the projects reviewed in this paper are part of the portfolio of projects that are sponsored by the Department at the National Laboratories while at the same time includes projects that are cost-shared with private sector and research partners in academia. The breadth of the portfolio illustrates the overall approach of the offshore research portfolio especially for enhanced oil recovery.
Recently the National Petroleum Council completed a study for the Secretary of Energy titled Meeting the Dual Challenge: A roadmap to at-scale deployment of carbon capture, use, and storage in which the potential for the use and potential long-term storage of CO2 used in enhanced oil recovery is considered for both onshore and offshore settings (NPC 2019).
Corrosion Experience with Low Carbon Steel R4 Grade Mooring Chain
Authors: Gabrielsen Øystein , Liengen Turid , Rørvik Gisle , Molid Solfrid , Stavang Terje 
Published: August 2021

Abstract
Equinor owns and operates a fleet of floating installations on the Norwegian Continental Shelf (NCS). As the installations are getting older, the importance of knowing the actual condition of the mooring systems has increased, and continuous mooring system integrity evaluation is important for the safekeeping of the assets. As a part of the mooring system integrity management, seabed chains have been replaced for condition evaluation, as in situ inspection techniques so far has not been able to determine the actual conditions of longer lengths of seabed chain. Thorough onshore inspection and full-scale fatigue and break load tests has been performed on retrieved chains, to map the actual condition and effect to integrity.
After retrieving seabed chains from approximately half of the floating installations, Equinor now has collected experience on chain degrading mechanisms and corrosion on different locations, water depths and different chain deliveries. The inspections have revealed several corrosion phenomena, where microbiologically influenced corrosion (MIC) due activity of sulphate reducing bacteria (SRB), is observed to have a significant effect on fatigue capacity. An important finding is also that corrosion mechanisms and severity change along the seabed chains.
In the Equinor fleet mooring chain grade R4 has usually been used. In total four different vendors have supplied chains, but the vast majority is supplied by two vendors. One of the mooring chain vendors have supplied low carbon (LC) steel chains for the larger chain diameters (larger than 114mm). A significant difference in corrosion is found between the low carbon steel R4 grade chains and other chains. Differences are found both for general corrosion, light surface corrosion and MIC/SRB corrosion.
This paper presents and discusses findings on MIC/SRB for seabed chains, in connection with the type of steel used in the mooring chain, demonstrating limited corrosion on low carbon steel chains. Also, special corrosion phenomena found only on low carbon steel chain is presented. These are found to have no or limited effect to integrity of the chains.
Consistency Under Applied Pressure Test CAPT - A Novel Method for Evaluating Pressure Effect on the Gel Time of Thermosetting Resin
Authors: Zhu Dingwei , Normann Svein , Xie Minli , Haugen Jonny 
Published: August 2021

Abstract
Thermosetting resin is gaining more acceptances in Plug and Abandonment due to its excellent mechanical properties after set and ability for placement in locations cement cannot reach. A thorough understanding of its curing behavior such as gel time is essential to ensure safe placement and a good seal. This paper investigates the pressure-sensitive gelation behavior of polymer resin under in-situ conditions, and the pressure effect on the gel time of thermosetting resin was evaluated.
An innovative assessment methodology named CAPT (Consistency under Applied Pressure Test) was created to assess the curing process of thermoset resins in a pressurized consistometer. A series of resin samples were tested at temperatures ranging from ambient to 120°C with applied pressures up to 10,000 psi. The consistency was initially used to indicate the gel structure development of the resin while it was gelling. Based on the consistency data, the relationship between applied pressure and gel time of resins was studied and a new approach of modeling the curing process with the influence factor of pressure was proposed.
The primary observation was the confirmation that the gelation process of thermosetting resin under applied pressure was faster than that under atmospheric pressure. However, the gel time had big variations. The pressure sensitivity mainly depended on the initiators and it was only partly dependent on the temperature. There was a threshold value for the pressure effect on the gel time. Below the threshold, the gel time only decreased by around 5%. Above the threshold, the pressure effect was much larger where the gel time decreased by 20% - 30%. This could be mainly attributed to the thermodynamic effect caused by pressure accelerating the polymerization process, resulting in a shorter gel time. Meanwhile, these results help explain why the curing behavior of thermosetting resin placed underground where high pressure is encountered often differs from the laboratory-predicted performance. Besides indicating the relative strength development, consistency analysis could also be used to assess the pressure effect on the gelation process of a resin sample in down-hole operations with applied pressures. Thus, CAPT would be more suitable than a conventional reactivity test to propose a new approach of modeling the gel time of thermosetting resin systems with the influence factor of pressure.
CAPT is a novel method to accurately evaluate the curing process of thermosetting resin and indicate its relative strength development. This helps engineers reach a good balance between designing proper operations and preserving mechanical properties in the plug and abandonment process.
Cost Effective, Digital, Fail-Safe Production Tree and Wellhead Actuator System
Authors: Johansen Espen Sten , Fredheim Dag Ketil , Volkers Richard , Hansen Dag Almar , Petersen Christian 
Published: August 2021

Abstract
E&P companies are challenged with the cost-effective development of smaller and marginal fields, while ensuring safety for its crew and facing increasing regulatory requirements for further reducing emissions and environmental impact. Key enablers to achieve profitable development of smaller fields and maintaining safe production in remote locations is digitizing and automating the production chain and limit the need for on-site personnel.
There are a number of safety critical valves on wellheads and production trees that have historically been manually or hydraulically operated and thus not suited for fully remote operations. In 2017, Equinor, Baker Hughes and TECHNI formed a Joint Industry Project (JIP) to develop a new electric actuator control system. The actuator system is designed for fail-safe, critical operations offshore and is subject to stringent safety design requirements. The key driver is reducing CAPEX and OPEX and environmental impact for offshore installations, while increasing availability of wells while providing improved monitoring and condition based, predictive maintenance.
The electric actuator system developed in the JIP has a patent pending fail-safe mechanism with extremely fast closing time to ensure well containment during critical situations. It is designed to be a drop-in replacement for existing hydraulic actuator solutions and is suitable for most standard wellhead and tree designs, sizes, and pressure ratings. The all-electric solution contains a multitude of sensors, that, in combination with an integrated digital interface, enables data-driven insights from the systems in operation.
The actuator development is currently at Technology Readiness Level (TRL) 4 on the API 17N, 0 to 7 scale. In 2020, the JIP consortium was awarded NOK 8.2 million (USD 950 000) by the Norwegian Research Council DEMO 2000 program to support the test and qualification program. TRL 5 testing is planned in first half of 2021 yielding it ready for field installation.
Novel Design Approach to Create Deep Water Metallic Buoyancy Modules
Authors: Loentgen Vincent , Maach Nouhaila , Brouard Yann , Verdeil Julien , Germanetto Florian , Lodeho Olivier 
Published: August 2021

Abstract
Buoyancy modules are widely used ancillary equipment aiming to shape riser systems to resist harsh offshore environments. Due to their thermoset polymeric nature, they are sensitive to the manufacturing parameters as well as subject to water absorption along their service life. To overcome the challenges of polymer-based buoyancy module, this paper explores the design of metallic buoyancy modules that can be 3-D metal printed.
An initial material selection is performed to identify suitable material candidates for the optimization algorithm. Steel and aluminum materials are considered and evaluated on a representative case combining density, mechanical stress and buckling criterion.
Then a topology optimization algorithm called ‘Adaptative Bone Mineralization’ is applied on the best candidate material, adapting their modulus of elasticity at each iteration according to the current stress distribution, load case definition and boundary conditions. The optimized design incorporates additional requirements related to additive manufacturing processes.
Results of the optimization algorithm are presented in a progressive order of complexity starting from the optimization of an angular section of 11.25 degrees opening with symmetrical boundary conditions up to a quarter of half-shell buoyancy module fully optimized in 3D. The optimization process log, capturing the volume fraction and the maximum stress at each iteration, is presented and compared with the selected set of criteria. Impact of the manual reconstruction process of the buoyancy module is assessed and the buckling stability is evaluated as a post-treatment. Two-dimensional and three-dimensional topologically optimized buoyancy modules are presented and comply with the strict mass requirement, stress criterion and buckling stability achieving deep water depth.
This novel design approach to create deep water metallic buoyancy modules achieves the tailoring of the buoyancy module's internal structure to maximize the buoyancy performance while ensuring its structural integrity.
Design Challenge of the West Nile Delta Gas Development: The Rosetta Channel Crossing
Authors: Gitahy Leonardo , Manso Daniel , Carvalho Guilherme , Lewis Mark , Migliaresi Dario 
Published: August 2021

Abstract
Raven is the third stage of the West Nile Delta development (following Taurus / Libra and Giza / Fayoum) from two BP-operated offshore concession blocks, North Alexandria and West Mediterranean Deepwater. The Raven project included the design of various rigid pipelines, of which one specifically is the subject of this paper. The 16" RSM to RP in-field flowline is approximately 4.8 km long, connecting a manifold (RSM) to a PLEM (RP) through a route that crosses a prominent geological feature identified as the Rosetta Channel, a submerged canyon that extends for about 30 km. The Rosetta Channel is about 2.5 km wide at the location of the 16" flowline route crossing, with steep slopes going down for approx. 40m (in height) on the RSM side, and then climbing up approx. 150m (in height) towards the RP side.
Although it is typically preferred to avoid very rough geophysical features, this is not always possible or practicable and it is not uncommon to come across challenging seabed features that demand complex engineering solutions in order to minimise risks and associated costs.
This paper addresses the numerous technical challenges involved in the design of the 16" flowline that crosses the Rosetta Channel. Following close collaboration between all involved stakeholders, a robust, reliable and cost-effective solution was achieved after a detailed engineering process, where the final design required a unique combination of mitigations including seabed excavation, pre-lay rock carpets, post-lay rock berms, cable jetting, curve bollards and sleepers.
Flow Assurance in Buzios Field: Key Challenges and Implemented Solutions
Authors: Noville Ivan , Maciel Milena da Silva , de Mattos Anna Luiza de Moraes y blanco , de Siqueira João Gabriel Carvalho 
Published: August 2021

Abstract
This article's goal is to present some of the main flow assurance challenges faced by PETROBRAS in the Buzios oil field, from its early design stages to full operation, up to this day. These challenges include: hydrate formation in WAG (Water Alternating Gas) operations; reliability of the chemical injection system to prevent scale deposition; increasing GLR (Gas Liquid Ratio) management and operations with extremely high flowrates.
Flow assurance experience amassed in Buzios and in other pre-salt oil fields, regarding all these presented issues, is particularly relevant for the development of future projects with similar characteristics, such as high liquid flow rate, high CO2 content and high scaling potential.