bluuebunny/crossref_metadata_2025_split huggingface dataset:
Key Technology Qualification for Increasing Subsea Well Production via Drag Reducing Agents
Authors: Schroeder, Jr. Arthur J , Chitwood James E. , Gay Tom A. , Gillespie John , Lee Yung , Hughes Paul , Verdeil Julien 
Published: August 2021

Abstract
Drag reducing agents (DRAs) are a cost-effective method to reduce pipeline pressure losses and maximize flowrates of onshore and offshore pipelines with over 40 years of proven results. With recent developments, production can also be significantly increased by injecting DRA into flow restricted subsea flowlines. This paper will provide a summary of the development and testing of a full-scale prototype subsea DRA storage and injection unit built to achieve the industry goal of alleviating flow restricted subsea pipelines. While DRA applications are proven in thousands of offshore and onshore applications, it has never been successfully injected subsea. System integration testing (SIT) is currently under way on the prototype unit, after which it will be qualified for offshore use. The technology is covered by numerous patents issued and pending in the US and other countries.
TRACS JIP – TTR Life Extension Process
Authors: Deka Dhyanjyoti , Campbell Mike , Patil Vinayak , Ge Michael Long , Wong Steve , Frame Tim 
Published: August 2021

Abstract
The Tensioned Riser Assessment for Continued Service (TRACS) JIP develops a structured life extension process for TTR systems including single casing, dual casing, buoyancy can supported and tensioner supported TTRs. The JIP bridges regulatory and API frameworks and achieves industry consensus on analysis, inspections, and documentation.
The life extension process developed in this JIP consists of detailed roadmaps that guide the operator through the different assessment steps starting from initial data gathering through to the development of the forward-looking IMP. The JIP life extension process is based on a threat assessment philosophy which ensures identification and assessment of all possible threats to the integrity of the TTR in its extended life.
The JIP process is validated against three real life TTR systems that are nearing the end of their design lives. Potential threats to the integrity of these TTRs during the projected continued service beyond the design life are identified and specific inspection and analysis recommendations to safely manage or mitigate these threats are made.
The JIP also provides TTR life extension analysis guidance while considering the opportunities to reduce conservatism compared to new designs. Inspection of TTRs is challenging due to accessibility issues and the pipe in pipe construction. Several subsea NDE inspection tools are surveyed in this JIP and their applicability to TTRs is discussed.
Research on Robust and Efficient Approach for Extreme Mooring Tension Estimation for FLNG and FOWT
Authors: Ando Tsubasa , Simon Wright Christopher , Wada Ryota , Takagi Ken , Watanabe Masaharu , Usami Akio 
Published: August 2021

Abstract
Offshore floating production units such as FPSO, FLNG, etc. are stationed at operation sites for many years without stopping operation. The mooring systems are provided as permanent positioning system for the floaters and are designed based on conditions that normally assume way longer than their actual service life. The offshore industry, nevertheless, has experienced higher than expected failure rates of mooring systems in the past. [1] Therefore, more robust and pertinent design requirements are desired. On the other hand, while operators demand more reliable design procedures, mooring analysis needs to be performed for numerous load cases on actual projects, which require enormous cost and resources for simulation and analysis. This has resulted in the need by the industry for more efficient mooring analysis procedures while maintaining the required safety.
Integrated Underreamer Technology with Real-Time Communication Helped Eliminate Rathole in Exploratory Operation Offshore Nigeria
Authors: Ozioko Raphael Chidiogo , Osita Humphrey , Ohia Udochukwu 
Published: August 2021

Abstract
This paper describes the successful deployment of integrated underreamer technology with real-time communication through mud-pulse telemetry system, to drill and eliminate rathole in 17 1/2-in × 20-in successfully in one run and helped set casing as close as possible to the depth of suspected pressure ramp on an exploratory well offshore Nigeria. This technology uses the same communication system (actuator bypass) as Measurement While Drilling tools (MWD), Logging While Drilling tools (LWD) and Rotary Steerable System (RSS).
Integrated underreamers broadly used in the drilling operations support optimized casing and completion programs and helps reduce operational risks such as wellbore instability. The ball drop and hydraulically activated reamer technologies available today comes with limitations and HSE risks. The distinctive functionalities of the integrated underreamer technology described here, such as unlimited and fast activation and deactivation via downlinking and real time downhole feedback, reduce uncertainties and operational costs in the complex and challenging deep offshore drilling operations.
The real-time communication through mud-pulse telemetry system enabled the placement of integrated underreamer 6 meters from the bit thereby reducing rathole length to approximately 9 meters compared to 80 meters for conventional underreamer application. The integrated underreamer is compatible with existing RSS and provide unlimited activation cycles. The integrated underreamer offers flexibility in placement in the bottom hole assembly (BHA) and it can be used as a near bit reamer, or as main reamer or as both. In this case, the integrated near bit underreamer eliminated the need for a dedicated rathole removal run. It also offered a feedback confirmation of the cutter blades activation status and provided hole opening log thereby reducing the operational uncertainties for the under reaming, saving rig time up to 16 hours for shoulder test.
The underreamer was successfully deployed to drill and ream the challenging 14 ¾" × 17 ½" and ream 17 ½" × 20" section offshore Nigeria. Both sections were drilled and reamed to section Total Depth (TD) in one run with all directional reuirements and Measuring While Drilling (MWD)/Logging While Drilling (LWD) met saving client approximately 4 days of rig spread cost. The reamer appeared to provide an in-gauge borehole allowing for successful running and cementing of liners without any issues, demonstrating superior borehole quality. The new Technology proved to be a reliable and flexible hole enlargement while drilling solution that help to improve drilling performance, reduce operational risks and save cost.
Advancing Effective Response Technology to Manage Containment of High Pressure, High Temperature Well
Authors: Goldsmith Matthew James 
Published: August 2021

Abstract
Deepwater well containment capabilities were born out of necessity – over the last 10 years the industry has innovated and improved upon capabilities and is currently focused on developing the systems required for, new high pressure, high temperature (HPHT) wells scheduled to be drilled in the 2021 timeframe.
As industry plans for drilling at deeper depths and higher temperatures – an organization's ability to keep pace with ever-changing needs is critical. That means continuing to enhance capabilities and technology to ensure well containment resources for the deepwater U.S. Gulf of Mexico are available.
MWCC is the first in industry to add High Pressure (20k psi) and High Temperature (400°F) technology to its portfolio. The development of this advanced technology presented many challenges both technical and non-technical. A shift from ram-based capping stack designs for well pressures up to 15K psi and temperatures up to 350F to valve-based designs rated for up to 20K and 400°F was necessary but presented technical challenges.
An extended flowback response to a HPHT well may requires additional supportive equipment to assure successful containment of well fluids. MWCC delivered novel technology in 2020 designed to cool well temperatures in order to continue use of conventional subsea architecture and systems.
Regulatory approval for HPHT source control technology is different from conventional technology. The approval of standard containment technologies is straightforward and well understood in industry; HPHT technology requires additional verification and approval. MWCC will address the process of obtaining approval for the use of HPHT containment equipment in an incident response.
Qualification of Metal 3D Printed Parts for Production Use
Authors: Vasquez Mike 
Published: August 2021

Abstract
As more organizations incorporate additive manufacturing systems to produce production parts, it is becoming clear that successfully moving beyond prototyping requires a more advanced and thoughtful qualification strategy. To achieve the desired outcomes, organizations in the oil and gas sector now need to learn how to build a methodical and scalable system for measuring and characterizing materials, processes, and parts. This paper will discuss an approach to solving this problem within the context of 3D Printing using metal powder. For both new and experienced users of this technology there needs to be a recognition that the workflow prior to and after printing are just as critical in producing repeatable parts as the machine operation itself. Additionally, the relatively small sample size of machine to machine comparison in the oil and gas sector raises questions about the best strategy to use when builing a supply chain to support productionazition of 3D Printed components. This paper addresses this challenge by showcasing new software tools to manage the data generated within sensors on production scale 3D Printers that can then be connected directly to the materials and post processing workflows to provide users with actionable data to manage and troubleshoot their production process with efficiency.
Pazflor Subsea Separation, Ten Years After
Authors: Bibet Pierre-Jean , Santos Redding , Lucas Antoine , Vunza Daniel 
Published: August 2021

Abstract
On Saturday the 3rd of September 2011, at 22h30 Luanda time, the first Pazflor gas/liquid Subsea Separation Unit (SSU) is put into operation, and one hybrid pump starts in production. Few weeks later, all three SSU are fully operational.
In 2021, all three SSU will celebrate 10 years of successful operation.
The paper relates 10 years of operational feedback of the Pazflor Subsea Separation Units with a special focus on the pumping system.
Triple MPD Technique for Drilling and Intelligent Completion Deployment on an Abandoned Deepwater Well
Authors: Fernandes André Alonso , Schnitzler Eduardo , Fabri Fabio , Grabarski Leandro , Malfitani Marcos Vinicius Barreto , Roman Roger Savoldi , Ascâneo Willian Medina 
Published: August 2021

Abstract
This is a case study of a presalt well that required the use of 3 different MPD techniques to achieve its goals. The well was temporary abandoned when conventional techniques failed to reach the final depth. Total fluid losses in the reservoir section required changing the well design and its completion architecture. The new open hole intelligent completion design had to be used to deliver the selective completion in this challenging scenario.
From the hundreds of wells drilled in the Santos basin presalt, there are some wells with tight or no operational drilling window. In order to drill these wells different MPD techniques are used. In most cases, the use of Surface Backpressure (SBP) technique is suitable for drilling the wells to its final depth. For the more complex cases, when higher fluid loss rates occur, the use of SBP and Pressurized Mud Cap Drilling (PMCD) enables the achievement of the drilling and completion objectives.
After the temporary abandonment of this specific well in 2018, the uncertainty of the pore pressure could not ensure that the SBP and PMCD techniques would be applicable when reentering the well. To avoid difficult loss control operations, the completion team changed the intelligent completion design to include a separated lower completion, enabling its installation with the MPD system. Besides the previously used MPD techniques, the integrated final project considered an additional technique, Floating Mud Cap Drilling (FMCD), as one of the possible contingencies for the drilling and completion phases.
Well reentry and drilling of the remaining reservoir section included the use all the previously mentioned MPD techniques (SBP, PMCD and FMCD). The lower completion deployment utilized the FMCD technique to isolate the formation quickly and efficiently, without damaging the reservoir. The planning and execution of the well faced additional difficulties due to the worldwide pandemic and personnel restrictions. The success from the operation was complete with no safety related events and within the planned budget. At the end, the execution team delivered a highly productive well with an intelligent completion system fully functional, through an integrated and comprehensive approach.
MPD use on deepwater wells is relatively new. Different operators used several approaches and MPD techniques to ensure safety and success during wells constructions over the last decade. This paper demonstrates the evolution of MPD techniques usage on deepwater wells.
Novel Active Slug Control in Angola - Development & Field Results
Authors: Brenskelle Lisa Ann , Morles Martin Bermudez , Flores Lauren Annette 
Published: August 2021

Abstract
Slug flow in multiphase flowlines can cause operational instabilities which, when severe, lead to mechanical damage or even shutdown of processing facilities. While a number of control schemes to handle slugging have been published, many of them require subsea instrumentation or make use of calculated "pseudo-variables" for control, values which have no real physical meaning. Hydrodynamic slugging was anticipated during design of a new facility in Angola, and a simulation study demonstrated that a control scheme from the published literature could be applied effectively to control the slugging. However, that solution was rejected because of the use of a pseudo-variable as the principal control point. Therefore, a novel control scheme was developed and tested on simulation for both hydrodynamic slugging and severe riser-induced slugging and later patented.(1,2) The project implemented the novel active slugging control using a topsides control valve and topsides instrumentation. While a pseudo-variable, a pseudo-flow controller, was employed, it was part of a cascade scheme such that the principal control variable was a real topside pressure measurement. Upon commissioning, slugging at the facility was found to be more severe than anticipated during design, but the novel active slug control scheme was effective in controlling incoming slugs.
Minimising the Risk of Hydrogen Embrittlement HE and Hydrogen Assisted Stress Cracking HASC Within Steel Lifting Products Used in the Marine Environment
Authors: Burgess Ben 
Published: August 2021

Abstract
Hydrogen Embrittlement (HE) and Hydrogen Assisted Stress Cracking (HASC) are processes that detrimentally affect certain steels. These processes are understood and well documented.
In recent years there has been an accumulation of product failures involving steel lifting components in the offshore industry. These failures have individually been investigated and confirmed as the result of Hydrogen Embrittlement (HE) and Hydrogen Assisted Stress Cracking (HASC).
There continues to be an assumption that steel lifting components that comply with international standards are suitable for use offshore, however the corrosive environment and effects of dynamic load amplification on lifting components in the offshore environment significantly increase their susceptibility to HE and HASC.
Our intention is to provide the offshore industry with technical guidance on the correct material selection in steel lifting components, over and above the requirements of international standards, to mitigate the risk of failure caused by Hydrogen Embrittlement (HE) and Hydrogen Assisted Stress Cracking (HASC).
Our research highlights that a high-grade steel's hardness and toughness is critical. The definition of toughness in metallurgy and lifting is the ability of the material to absorb energy and to plastically ‘deform’ without fracturing.
Design and Installation of Leading Edge, Practical and Economic Mooring Systems for Commercial Scale Floating Offshore Wind Energy
Authors: Fulton Tom , Arikan Yusuf , Miller Regan , Longridge Jonathan Kent , Campbell Mike 
Published: August 2021

Objectives/Scope
As Floating Offshore Wind moves from demonstration and pilot projects to full commercial scale, there is a need for mooring systems to be practical and economic while providing safe and efficient stationkeeping for floating wind turbines. Mooring systems for floating offshore wind must be designed to meet the needs to provide a reliable stationkeeping system, satisfy turbine motions criteria for maximum energy production, accommodate electrical power transmission cables, allow for other marine users (e.g., fishing vessels, service vessels for inspections and maintenance, etc.) and be environmentally friendly. To be commercially viable, this must be done with an understanding of the need to moor 30 or more turbines in close proximity to one another with hundreds of mooring lines. To accomplish this, there is no one perfect mooring system for all projects. This paper will investigate multiple mooring solutions including various configurations and material types and will reveal both the technical and commercial benefits of the various systems.

Methods, Procedures, Process
Multiple mooring systems will be designed to accommodate a 15 MW floating wind turbine. An installation methodology will be developed, and the supply chain will be investigated to enable calculation of the total installed cost of each system.

Results, Observations, Conclusions
The stationkeeping performance of each system will be compared as well as the economics for a large scale commercial floating wind farm. While no one system will be the clear best for all projects, guidance will be given which can aid in the selection of practical and economic mooring systems.

Novel/Additive Information
The paper will investigate multiple viable mooring systems from the design, procurement, and installation viewpoint to develop total installed cost estimates. This will be done while evaluating these mooring systems for a large commercial size floating wind farm while addressing the need for the supply chain to deliver industrialized solutions to deal with the large scale.
Friction Reduction Technology Tailored to Extreme Flow Rates
Authors: Trinh Khoi Quang , Xia Yufang Sandra , Franco Tamara Santiago , Perez Daniel , Emuchay Chigozie , Che Roman Vladimirovich 
Published: August 2021

Abstract
Non-thru bore drilling tools often feature limited flow range capabilities due to their design complexity. An ever-growing demand in high flow rates required a new technical solution that has the lowest possible pressure drop across the tool. Potential erosion issues as well as consistent functionality of the tool were key design requirements. A new friction reduction technology is presented that addresses the applications with flow rates ranging from low to high.
Initial computational fluid dynamics (CFD) analysis suggested the flow split can be executed by restriction at the tail end of the power section. This, however, was challenged by the first test run that took place at 550gpm (5¼-in. tool outside diameter [OD]). While the run objectives were met in its entirety, upon tear down, the early signs of erosion were noticed on the valve assembly. With this evidence on hand, a critical design change was implemented, and as a result, the restriction was moved down the power section to spare the vortex at its tail end. Further improvement was retrofitted to protect the restriction itself with a simple addition of a sleeve.
Further field runs were executed with the new tool setup. As the run count progressed, the newly redesigned technology achieved the objectives by delivering effective friction reduction at consistent frequency and pressure drop. It soon became evident that the step change in flow rate did not affect the tool wear and tear.
Since its inception the tool has set two field records. The first commercial run marked the fastest curve in the county. As this technology rises to prominence in the US and international markets, more operators are experiencing the savings and lower Authorization For Expenditure (AFEs).
The novelty of the design presented in this paper is in the drilling engineer's ability to design and construct wells with increased complexity (high dog leg severity [DLS], directional difficulty index [DDI], extended reach, and multi-lateral) where friction reduction technologies are critical to achieving run objectives. This technology fills a technical gap by meeting the new standards of high torque and flow rates in a compact and robust design. At the time of this writing, no other friction reduction technology meets these tool specifications.
Utility of Nested Reverse-Transcriptase Polymerase Chain Reaction of Clinical Specimens for Early Diagnosis of Hemorrhagic Fever with Renal Syndrome
Authors: Seo Jun-Won , Kim Da Young , Kim Choon-Mee , Yun Na-Ra , Lee Yu-Mi , Lawrence Panchali Merlin Jayalal , Kim Dong-Min 
Published: August 2021

ABSTRACT.
Hemorrhagic fever with renal syndrome (HFRS) is confirmed by the isolation of hantavirus from serum, detection of virus-specific IgM, or a four-fold change in IgG titers during the acute and convalescent periods measured using an immunofluorescence assay (IFA). However, these tests are inefficient for early diagnosis. Therefore, this study investigated the usefulness of reverse-transcriptase nested polymerase chain reaction (RT-nPCR) for early diagnosis of HFRS using clinical samples such as urine and serum. Electronic medical records of eight patients with confirmed HFRS using IFA and RT-nPCR between May 2016 and May 2020 at Chosun University Hospital were reviewed. The virus was detected in all patients using RT-nPCR targeting the large (L) segment of hantavirus during the early phase in urine and serum. Importantly, the virus was identified in urine at a time when it was not identified in serum. Additionally, the virus was detected in urine and serum for up to 1 month after initial presentation with illness, but not in saliva, using RT-nPCR. We report eight HFRS cases diagnosed using urine and serum, but not using saliva, with RT-nPCR targeting the L-segment. Hantavirus RNA detection by RT-nPCR in urine and serum may aid the rapid diagnosis of HFRS during the early phase of the disease. In particular, HFRS should not be ruled out based on negative RT-PCR results in serum, and RT-PCR should be performed using urine as well as serum during the early phase of symptoms.