bluuebunny/crossref_metadata_2025_split huggingface dataset:
Managing Subsea Safety Critical Equipment and Design Performance Standards in Major Capital Projects – Mad Dog 2 Project
Authors: Ong Chee Seang , Smelser Amanda Marie 
Published: April 2023

Abstract
For an offshore facility, identifying Safety Critical Equipment (SCE) and ensuring that they are designed, built, installed, and commissioned based on certain performance criteria are key to a safe design. In some parts of the world such as the North Sea, regulatory requirements dictate a mandatory third-party verification of the SCE and their corresponding design performance criteria. However, in other parts of the world such as the Gulf of Mexico, there is no such regulatory requirement. It is therefore up to the operator to provide assurance that the subsea SCE meets the design criteria. There exists no comprehensive guidebook for this type of assurance in the Gulf of Mexico. This paper exemplifies one potential methodology for establishing and implementing SCE design performance standards for a Subsea Production System, and shares some of the challenges from the BP Mad Dog 2 project (Argos platform) with managing the verification process, especially in a complex project organization where multiple contractors participate.
Management of the subsea SCE design performance standards involves identification of the SCE, development of the relevant design performance criteria, and a two-step process to track each design criteria outcome via engineering assurance and field verification - where the design criteria is tested either at the manufacturing site, construction site, or during post-installation testing and commissioning activities. The activities presented were performed entirely via digital documentation, utilizing regulatory and industry standards, project specifications, vendor records, testing results, and commissioning procedures. Verification assurance and approval forms were digitally processed and tracked by using a subsea SCE design performance standards verification register.
This paper shares several key learnings that will benefit the industry and future projects aiming to implement a robust subsea SCE verification process.
How American Based HVDC and OSS Offshore Wind Substations can Profit from the European Learning Curve
Authors: Groeneveld Berend , Gerssen Sietse , Hoogakker Petra 
Published: April 2023

Abstract
The USA has committed to significant investments in offshore wind energy and is expected to quickly catch up with European investment levels. The federal government has committed to deployment of 30 gigawatts of offshore wind by 2030 [1].
Due to the nature of the energy function of offshore wind substations, risk assessments allow for different, generally less onerous, fire and blast ratings of architectural items as compared to the standards prevalent in the offshore oil and gas industry.
The most commonly used standard for offshore wind substations is DNV-ST-0145. This standard is regularly updated.
This paper is based on lessons learned from the design process utilized on a total of 55 European offshore wind substations and 5 USA offshore wind substations, all based on the DNV standard.
Lessons learned are taken from the design of European substations over the past 15 years. The lessons learned are translated to meet American offshore norms and standards, allowing the architectural design and build of USA based substations to be executed swiftly and effectively. These lessons have been implemented in the architectural design of the first five American substations. A number of standard and USCG/DNV approved details are provided, including details of penetrations where architectural, structural, piping, HVAC and Electrical disciplines are aligned.
Conclusion: USA based offshore wind projects have ample opportunities to "leapfrog" the learning curve already realized by European projects and immediately adopt the resultant design philosophy for HVDC and OSS offshore wind substations. Provided local production norms and standards of transition of support steel to USA dimensions are incorporated in the design.
This results in an approved, standardized and economic architectural design model for the fabrication of USA based and produced substations. The application of this standard could shorten lead times and production times significantly.
Moving High Loads with Low Power Subsea – How a Novel Electric Actuator Technology Enables a Sustainable Energy Transition
Authors: Alexandre Orth , Markus Kubacki , Gottfried Hendrix , Joao Pedro Duarte da Silva 
Published: April 2023

Abstract
The offshore energy industry relies on heavy-duty equipment to execute complex operations in harsh environments over a long time with remote control and limited maintenance. But how is this equipment powered and controlled to enable reliable and safe operation? Hydraulics have been often used because of the high robustness and safety; but hydraulics also include complex installation, low energy-efficiency and potential environmental risks. On the flipside, subsea electrification seems cost-intensive due to its high power and large batteries needed.
This paper explains how a novel subsea electric actuator technology enables a sustainable energy transition combining the ability to move high forces while being cost effective. For CO2 storage, it enables an all-electric subsea tree, comparable in price to a traditional hydraulic tree, but without demanding expensive umbilicals or topside hydraulic power units. In applications requiring long control distances, such as oil & gas fields with long subsea tiebacks or deepsea mining, it allows safe and reliable operation with minimal electric power consumption, capable of precisely handling even high loads.
Site Selection for Field Testing of a Marine Hydrokinetic Turbine Platform to Serve as a Floating Unmanned Mobile Recharging Station for Aerial Drones
Authors: McKinney Adriana Lynell , Rienzo Hayley , Pimentel Hugo , Frankenfield John , Beaujean Pierre-Phillip , Dhanak Manhar 
Published: April 2023

Abstract
Expanding applications of unmanned aerial vehicles (UAVs) in coastal areas suggests a need for stations along or close to the coast where the UAV batteries can be easily recharged. A small-scale low flow marine current turbine in support of a floating autonomous recharge station for small UAVs has been designed and assembled at Florida Atlantic University and is being prepared for field testing. Surveys of identified test sites in the Intracoastal Waterways and at open ocean locations are being conducted to determine their suitability in meeting resource, system design and permitting requirements. A sensor platform has been developed for measuring local currents at the identified sites in support of resource characterization. Two out of the eight sites surveyed in the Intracoastal Waterways are found to meet the field-testing requirements for current resource, water depth, and sea bottom conditions. Planned field testing will include parametric characterization studies of the performance of the current turbine for a range of turbine blade configurations, current speeds, turbine wheel submergence levels, and test site location (channeled flow vs open ocean flow).
Wire Arc Additive Manufacturing for Subsea Components – The First of a Kind 3D Printed Subsea Flange
Authors: Arcangeletti Giorgio , Santicchia Angelo , Terracina Salvatore , De Cesare Domenico , Palmirotta Luca , Moulin Jonathan , Kling Isabelle , Mathew Jithin , Faivre Laurent , Lefèvre Fabien 
Published: April 2023

Abstract
Additive manufacturing is gaining increasing interest as an alternative manufacturing process to produce conventional or engineered materials for pipelines. In this context, during 2021 Saipem launched an R&D initiative to explore the possibility to deploy Wire Arc Additive Manufacturing Process (WAAM) to produce typical components of a subsea pipeline system.
The main objective is to demonstrate that WAAM is suitable to produce pieces having similar properties than the ones manufactured via traditional methods and that they could be used for typical offshore components.
As a first trial, Saipem decided to start with the production and testing of a subsea flange and the scope was assigned to Vallourec S.A. Scope of the present paper is to share the main challenges faced during the activity and the main outcomes of it.
The selected grade was an ASTM A694 F65 equivalent grade that is considered a representative case for several offshore scenarios and the produced flange was a WELDING NECK 11" API 6A (10.000 psi) which represented in terms of WAAM technology the largest part ever printed by Vallourec. Manufacturing, inspection, and testing has been carried out following the requirements of DNVGL-ST-B203 for AMC 3 category.
After the printing of a pre-build piece to verify the main properties and to confirm that the parameters were suitable for the production, the full-scale component was then printed as well and destructive testing has been done in critical areas of the piece after NDT inspection.
Human Resource Program for Integrity Management and Life Assessment: Subsea Cases Application
Authors: Costa Celio Albano , Costa Marysilvia Ferreira , Drumond Geovana Pereira 
Published: April 2023

Abstract
Integrity management and life assessment is very demanding in all industrial applications and, in high deep subsea, to keep the structural integrity of all components safe is critical. Failure is a process that has time on its side and, if catalyzed by aggressive media, temperature, and pressure, leads to many possible combinations of damage mechanisms.
One can easily visualize the corrosion in metals or degradation in polymers, which may result in crack nucleation and its subcritical growth. Fatigue is also part of the life reduction process, associated or not with environmental effects. The damage process is not constant in time, but changes as the well reservoir is depleted and with the action of the environment itself. For instance, the presence of high quantities of CO2in Santos Basin (pre-salt) and its effecton structural integrity and corresponding life assessment demands a great deal of studies (for the past-used pieces of equipment and future ones – such as TCP). Failure can happen in localized parts, not necessarily leading to the whole component malfunction, but it will shorten its operation life. The failure process begins at the namo or microscale, a locus of metallurgical and materials engineering expertise, where small-scale samples are tested and evaluated; and then moves to structural macroscale analysis, where medium/large scale tests and analysis/modeling are conducted, the locus of mechanical, civil, or naval engineering. To skill a metallurgical/materials engineering to understand global structure behavior is as important as to skill a mechanical/civil/naval engineering with microscale behavior in a major/minor academic formation. To tackle this demand in Brazil's oil & gas sector, the Brazilian Petroleum Agency (ANP) established a human resource program to support the Integrity Management & Life Assessment in subsea operations and renewable energies, named PRH 7.1.
This paper will report on the PRH 7.1 academic structure to supply human resources for the oil & gas sector, focused on Integrity Management & Life Assessment. It will also show three examples of ongoing research in the program: Case 1: Design and construction of a permeation cell and the measurement of CO2 permeation in PVDF; Case 2: Theoretical and finite element analysis of a laminated composite pipe under combined axisymmetric loading; and Case 3: Study of nonlinear structural behavior during the operation of installation of subsea equipment.
Successful Application of Foamed Cement Slurry in an Ultradeepwater Well of 11,900-ft Water Depth (Claiming World Record)
Authors: Nzoutchoua Degaul Nana , Johnson Carl R. , Tenin Jean Yengoua , Lonca Matthieu , Sousa Edevaldo Andrade e , Zghal Jamel 
Published: April 2023

Abstract
Foamed cement was successfully used in the riserless section of an ultradeepwater well located in 11,900ft water depth. Foamed cement was selected to minimize operating costs and provide flexibility to adjust slurry density on a short notice. The seawater column exerted 5,319.1-psi hydrostatic pressure on the annulus. Consequently, nitrogen (N2) density could no longer be neglected. This paper presents simulations performed in preparation for the job, operational considerations, and post-job evaluation.
The lead slurry needed a density of 1.25 SG and develops a compressive strength of at least 300 psi within 48 hr. Considering the cost and challenges associated with outsourcing resources under current Covid-19 pandemic restrictions, the foamed cement system was preferred over chemical- or particle- extended cement or blend systems. The N2 ratio for the foamed cement slurry system was 700 scf/bbl. With a base slurry pumping rate of 5 bbl/min, the required N2 pumping rate was 3,500 scf/min, which was greater than the capability of a single N2 pump (3,000-scf/min rate). Because the rig deck space could not accommodate three N2 pumps, one pump would serve as backup; thus, the final plan consisted of using two N2 pumps simultaneously. Two parallel foamed slurry treating lines were rigged up to reduce the fluid velocity in a single line.
All laboratory testing was conducted locally. Additives used in the foamed slurry were environmentally friendly. A proprietary process-control system was used during the cementing operation and automatically synchronized the N2 pumps and foam pump rates with the base slurry rate. The cementing crew consisted of 11 individuals, including 2 client representatives. The entire pumping operation was completed in 10 hr. A total base slurry volume of 1016.2 bbl was continuously mixed and pumped at the density of 13.35 lbm/gal (1.60 SG). The resulting foamed slurry volume was 1387.0 bbl with an average foam quality of 27.8% and foamed slurry density of 10.5 lbm/gal (1.26 SG). A total of 119 metric tonne of class G cement and 30,711 L of N2 were consumed during the pumping operation. The lead slurry was followed by 603.9 bbl of 15.86 lbm/gal (1.90 SG) class G cement tail slurry and 349.7 bbl of seawater for displacement. The final surface pressure was 594.6 psi. The lead slurry reached the seabed and the float shoe check was positive. No casing subsidence was observed.
Using foamed cement slurry in such extreme conditions demonstrated its robustness and reliability. Through formalized and methodical risk assessment, the team was able to identify and implement mitigating measures that led to an outstanding result. This application also confirmed that N2 density should not be neglected when high-hydrostatic pressure is involved.
Vito Project: Drilling & Completions – World Class Riserless Batch Set Performance, Best-in Class Deepening Performance, In-Well Barrier Gas-Lift System, 17 Ksi Barrier Checks, 15 MMSCF/Day Injection Rate
Authors: Rabei Rob , Freeman Steven , Adams Eli , Pillai Pradeep 
Published: April 2023

Abstract
In 2009, the Vito field was discovered in more than 4,000 ft of water approximately 150 miles offshore from New Orleans, Louisiana. The project produces from Miocene-aged reservoirs nearly 30,000 feet below sea level. The Vito project was the first deep water project to require in-well retrievable gas-lift systems with metal-to-metal seals capable of sustaining a differential of 17 Ksi and injection rates of 15 MMscf/day. This paper provides an overview of Vito's drilling and completions, in-well gas-lift system, development process, validation and testing requirements, key challenges encountered during the project, and the technologies. This paper is part of a Vito Project series at OTC 2023, and the other papers are listed in the references.
The Vito Phase 1 project consisted of 8 producer wells with slim hole and open hole gravel pack design. The project wells were drilled with an Ultra-Deepwater Dual-Activity rig. The Gas-Lift Development Team worked with vendors to identify technology gaps with existing gas-lift system to project requirements. A validation process was created by the project using the following standards: API 19G 1,2,3, QAQC, ASME, FEA, CFD & Non-metallic Standards, company standards along with partner TR2385 document to establish design, manufacturing, and validation testing guidelines to ensure the highest level of reliability possible for a gas-lift system. The project team worked alongside the vendors to design and test concepts that eventually became the project's gas-lift system.
The riserless section was drilled in a batch form and was benchmarked as a world-class performance against the company fleet performance. The majority of the subsequent deepening drilling and completion operations were benchmarked as best-in-class performing wells, thanks to the implementation of competitively scoped well designs, vendor engagement and well on well learning curve improvements. The gas-lift system key challenges included understanding the phase envelope of the injection gas and potential issues that may provide for long term integrity of the well, locating testing facilities to handle 10 Ksi injection pressure with up to 15 MMscf/day of injection rates, welding and heat treatment of Inconel side pocket mandrels, long term Arrhenius testing of non-metallics, developing robust QCP plans for manufacturing, and conducting an in-well SIT (systems integration test) of the KOT (kickover tool) systems.
A Subsea Wellhead Solution Ready to Meet Challenging and Critical Endurance and Performance Needs
Authors: Amini Shakib , Potter Philip , Attaway Daryl , Bornia Guaraci , Zhu Baozhi 
Published: April 2023

Abstract
Subsea annulus seals are a critical part of a subsea wellhead system installation. The evolving need to achieve greater annulus pressure and extended lockdown performance is ever present while combined with the need to install in as timely an operation as possible. It is crucial to ensure reliable installation, coupled with the knowledge that the annulus seal is installed correctly to achieve the design performance as qualified in lab settings.
This paper discusses the design and testing of a high pedigree subsea annulus seal utilized in challenging environmental conditions and discusses features introduced to the seal and installation tooling to ensure confidence in long term integrity of the system.
A New Subsea Station for Deep Gas Treatment Allowing to Maximize Subsea Gas Fields Production
Authors: Roland Paul , Vasquez-Quintero Felaurys , Pouplin Amelie , Shaiek Sadia , Giolo Riccardo 
Published: April 2023

Abstract
The offshore oil & gas industry is presently interested in exploring and developing ultra-deep gas fields for which the water depth is higher than 1,500 m. Considering the water depth and the characteristics of these reservoirs, the exploitation of such fields represents a challenge. To unlock these reserves, it is necessary to tackle obstacles like lack of available pressure, risk of solid deposits (hydrate, wax), and liquid accumulations in low points of the exports line(s). To cope with these issues when the field architecture is not sufficiently flexible (for example, if the number of export lines is limited), one solution is to remove the liquids before production in gas line.
SUBGAS has been developed as a potential solution to these challenges and can be implemented over a wide range of application cases. SUBGAS is a subsea station that performs gas/liquid high performance low temperature separation (LTS), allowing gas dewpointing to be performed in subsea conditions. This subsea processing station performs a liquids and condensable components removal from the production gas coming from wells. The treated gas leaving the station is exported alone in the export line(s) while the liquids and condensable components are exported to shore via a dedicated line. Due to the dewpointing operation, the pressure drops in the export gas line(s) are reduced, hydrate and/or wax formation risk is avoided or significantly reduced, and the operability of the line is improved as there is no or a very low amount of liquid.
Based on numerical studies, a technical comparison with typical gas/liquid (G/L) separation, subsea compression, and other dew-pointing technologies is presented to highlight advantages of the proposed solution. Then, the SUBGAS station process and design is highlighted through a specific study case. An assessment of the Technology Readiness Level (TRL), according to API 17N, of the solution has been also done showing a high level of maturity allowing a rapid time to market.
By performing a gas treatment to remove liquids and condensable components, SUBGAS subsea station proposes an innovative solution to improve gas fields production via long subsea tie backs. Due to its simple process, high robustness, high maturity level, and considering the possibility to be used for brownfield long tie-back development, SUBGAS can be one of the keys allowing to maximize gas fields productions in the coming years.
Active Magnetic Ranging While Drilling: Performance Test
Authors: Husby Karsten , Saasen Arild , Ytrehus Jan David , Hjelstuen Magnus , Koraei Mostafa , Liberale Allesandro , Eriksen Tor Jan 
Published: April 2023

Abstract
During the well intercept drilling enterprise, several wireline logging operations are being run. The drill pipe is pulled out of the well and a wireline tool is run in. From the wireline tool a very low frequency alternating current is emitted into the formation to reach the target well casing. Then the electric current runs down the casing and back into the bottom of the relief well. This current set up a variable magnetic field that is measured by magnetometers in the relief well. Thus, the direction towards the target well can be determined. The drilling direction is accordingly adjusted, and drilling is continued. Typically, a number of 10 – 25 similar wireline navigation runs are needed before the target well is intercepted. The operation with pulling drill pipe out of the well, running the wireline operation and finally running the drill string back into the well typically cost several days drilling time. A prototype of a tool for Active Magnetic Ranging While Drilling has been developed. The scope of using this tool is to perform similar logging operations as currently being performed with the wireline operations, with an integrated tool systems on the relief well drill pipe. Thus, all the tripping operations are avoided and the time to drill the relief well is significantly reduced. This tool is described in detail in the following. Focus will be given to performance tests conducted in the laboratory and in a research well in Norway. A drill pipe is placed in a target well. Then a drill pipe including the measurement tool is run in a neighbour well and the direction and distance to the target well is measured. The set-up and results of this logging operation conducted on a drill pipe is described in detail.