bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Operation of Fluid-Loss Isolation Barrier Valves in Debris
Authors: Craik Steven J. , Jannise Ricki , Barrios Oscar , Tocchetto Andre , Soares Robson 
Published: April 2018

Abstract
This paper demonstrates the importance of wellbore cleanliness during lower, intermediate, and upper completion installations that lead to both successful installation and operation of an isolation barrier valve. This should result in bringing the well into production or injection in a timely and efficient manner. Excessive debris remaining in the wellbore can complicate and delay production or injection and also compromise well productivity by causing damage and preventing installed equipment from operating properly. Post-production/injection debris in the well can also impact and affect production and injection rates.
Downhole tools in deepwater environments not operating remotely as designed because of debris can result in a complex and costly intervention. Typically, when this occurs, a drift or bailer run is conducted to establish holdup depth. In some cases, these have tagged up to 50, 80, and 100 ft (in extreme cases, 150 ft) above the valve expected to operate. Sometimes, slickline, electric line (e-line) bailers, coiled tubing (CT), or a work string with a Venturi junk basket are used, and then the valve is either functioned open or the debris is milled out and the valves remotely functioned cycled open once all the debris is removed. Additionally, cases have occurred where the debris is cleaned out, enabling the tool to function and open, depending on tool design. The tools can be designed and qualified to industry standards and tested at downhole conditions, pressure, and temperature with applied tubing and simulated hydrostatic pressure; however, this does not mean functionality cannot be impaired. The importance of wellbore and surface equipment cleanup should not be undervalued.
Wellbore cleanout, circulation, displacement, and correct conditioning of fluid are important during the final stages of the operation. If executed properly, these can result in the well entering production or injection on time and without issue. The criticality of robust procedures cannot be overlooked. Not only is it important to condition and displace drilling fluid with clean completion fluid, it is also important to ensure that all debris is removed, including jetting the blowout preventer (BOP) and wellhead cavities before running the completion. Additionally, particular attention should be given to the landing string, tubulars, and drillstrings used to land and lock the completion. All surface lines and pump cavities should also be cleaned before pressure testing. Due diligence during initial cleanout can enable successfully bringing the well on-stream and help prevent costly interventions.
4D-Close-the-Loop Workflow to Calibrate the Geomechanical Simulation Model and Identify Drilling Geohazards: Field Application
Authors: Nasser Yesser Haj 
Published: April 2018

Abstract
Anomalous time shift observations from 4D seismic data shot in an HPHT field in the North Sea are being investigated. We are using these time shift signatures to understand the dynamic geomechanical behaviors of two major shales units (Shale Ι and Shale ΙΙ) between the main producing sands.
To capture the geomechanical and pressure diffusion behavior in these shale units, we have performed a coupled fluid flow and geomechanical simulation. Next, we use a 4D-Close-the-Loop workflow to integrate reservoir simulation results, the rock physics model, and seismic signature into a comprehensive and iterative process to update the simulation model. In this process, geomechanical modeling and the conversion of model results to synthetic 4D seismic time shifts allow for a quantitative comparison of synthetic response with the observed 4D seismic anomaly.
The application of this hands-on approach has prompted the calibration of the fluid flow and the geomechanical properties of different reservoir units. Consequently, a better match between the modeled 4D seismic time shifts and those observed from the field data has been achieved. Furthermore, this calibration provides a model that more reliably predicts the pore pressure and stress tensor changes, allowing more confidence in selecting safe well paths. The calibrated geomechanical model suggests that Shale Ι, which is a silty marine shale, undergoes pressure diffusion, and therefore, the trapping mechanism of Shale Ι is highly uncertain. The clay-rich Shale ΙΙ, however, acts as an effective pressure barrier, and hence it is overpressured relative to the surrounding formations and could be a high-risk formation for future drilling programs.
In this case study, the application of the 4D-close-the-loop workflow allows the calibration of the geomechanical model, and hence a close examination of stress distribution at the level of Shale Ι and Shale ΙΙ. These findings have provided additional information that could identify potential geohazards and prevent the risk of well deformation and failure.
Experimental Investigation of the Ionic Strength Effects on Drag Reduction Characteristics of Polymer Solutions – Part I: Straight Tubing
Authors: Kamel Ahmed H. 
Published: April 2018

Abstract
It is well established that polymers are successful drag reducers due to their viscoelastic properties that can suppress the turbulence eddies and fluctuations and hence, reduce friction pressure losses. Various factors can affect the polymers’ drag reduction characteristics such as polymer type, concentration, shear degradation, and flow geometry. However, few studies have shown the effects of salt type and concentration on drag reduction characteristics with almost no studies discussing their effects in the light of the ionic strength. The ionic strength is considered a more widespread scale to quantify the effects of salt contents on a specific characteristic. This study is undertaken to better understand the relation between ionic strength and drag reduction performance of polymers in straight tubing.
For this purpose, two widely used anionic AMPS copolymers; Nalco ASP-700 and ASP-820, are investigated. The salt matrix includes 2% KCl, 4% KCl, and synthetic seawater. For synthetic seawater, different recipes exist. The recipe adopted includes 1.0 lb/bbl Na2SO4, 10.5 lb/bbl NaCl, and 0.4 lb/bbl CaCl2. A ½-in. OD flow loop with a 15-ft. straight tubing section is used.
The results show that drag reduction behavior is better correlated with the solution ionic strength, and not the salt concentration. Higher ionic strength yields lower drag reduction despite the lower salt concentration. However, the adverse effects of salt and its ionic strength diminishes as higher Reynolds numbers. Both ASP-700 and ASP-820 exhibit a very effective drag reduction behavior and their performance is significantly affected by the polymer type, shear rate, and salt content. Correlations between ionic strength and drag reduction ratio for both polymers are proposed. The correlations exhibit a reasonable agreement with the gathered experimental data. They can be used to quantify the adverse effects of different salt types and concentrations on drag reduction characteristics of polymers in straight tubing
Remediation of Subsea Flowline Restriction Using Seawater and Additives
Authors: Garan Ron , Esley John , Arciero Bryan , Mazzeo Claudia , Alapati Rama , Yousef Ali 
Published: April 2018

Abstract
Prior to a planned transition in producing zones, an 18,000′ single well subsea tieback flowline to a deepwater Gulf of Mexico production facility experienced a restricted flowline ID and partial blockages due to paraffin deposition. Efforts were coordinated to provide support in the design, product selection, and determination of success for the flowline remediation. Transient multiphase flow simulations were created and tuned/validated with historical slugging data to estimate initial effective ID of the subsea flowline. The models were then applied to the planned clean-out procedure to develop performance indicators during and after flushing operations. A two-step remediation consisting of a 24 hour hydrocarbon solvent/dispersant mixture soak, followed by a 4,000 bbl seawater and waterbased paraffin dispersant flush at increasing rates utilizing solvency, dispersancy, and shear was used to remove deposition and increase cross-sectional flow area of the pipeline by 85% (initial effective ID ~2.5 in., final effective ID ~3.4 in.). The procedures were created to minimize risk of packing solids following initial disaggregation, while maximizing effectiveness of the flowline clean-out within the economic constraints of a depressed oil market.
Development of a Casing-Integrated Well Control Tool
Authors: Owens Zach , Smyth Brian , Ames Nicoli , Pye John , Hilbert Lawrence , Brooks Bob 
Published: April 2018

Abstract
This paper documents an initiative to develop a surface-activated, casing-integrated, flow-restriction tool capable of arresting flow during an uncontrolled blowout. The tool is similar in function to a subsurface safety valve (SSSV) but is designed to fit directly into a 9-5/8-inch casing string. Unlike a SSSV, the well restriction tool (WRT) described here is intended for use during drilling operations and can be installed deep in the well near the end of the casing string. The WRT is intended to supplement the blowout preventer (BOP) by arresting the influx of hydrocarbons into the well thereby increasing the chances that the BOP can successfully close, and by serving as a backup in cases where BOP closure is unsuccessful. Actuation of the device is accomplished by remotely triggering the combustion of a propellant charge which drives a sleeve forward and releases six, spring-loaded, triangular fingers which come together to seal the wellbore. This work describes the conceptual operation of the WRT and the design basis for the tool; including, computational fluid dynamics (CFD) analysis and finite element analysis (FEA). Lastly, initial prototype testing will be presented culminating in a successful closure and leak proof hydrostatic test to 10,000 psi.
Modular Compact Pump: A Game Changer in Subsea Multi-Phase Boosting
Authors: Melbø Aslaug , Glomsaker Terje , Sundt Hans Kristian 
Published: April 2018

Oil companies are looking for ways to increase oil recovery rates. Subsea boosting can be a powerful tool, but investment costs are often too high, driven by expensive topside modifications and overall system cost. Operators also see other challenges for future boosting systems which are not currently solved by conventional systems, in particular being able to provide sufficiently high boost for deep, long tie-back fields, as well as avoiding a barrier fluid system.
The Modular Compact Pump (MCP) is a barrier fluid-less pump, based on an entirely new subsea pump architecture which enables flexible high boost solutions at low life cycle cost. Due to the novelty of the concept, with each impeller spinning independently, an early phase prototype approach was chosen to prove the feasibility, both electrically, hydraulically, and mechanically. A small-scale 3-stage prototype was successfully tested during the second half of 2017, and key results from the test are presented.
CVA for the Continued Service Process - A Proposal
Authors: Gallagher Dan , Spong Robert , Abadin Jose , Rose Christopher 
Published: April 2018

Abstract
For Continued Service (Life Extension) approval in the GOM, both BSEE and USCG require a review of the process and submittals by an independent third party. This has been referred to as a CVA review for lack of a better term, which is a Certified Verification Agent. However, the scope of a CVA review during a Continued Service Assessment does not typically warrant the extensive scope of the full CFR definition of a CVA as required for the design and installation of a new offshore facility, but guidance has not yet been provided by USCG or BSEE. As a result, there is currently uncertainty within the industry as to what the CVA role is for Continued Service and it is being applied using widely varying approaches, ranging from a simple review of the overall assessment documents and references to active participation in the entire process influencing decisions on analysis and mitigation requirements. Drawing upon the authors experience conducting Continued Service Assessments in the different roles of operator, assessment contractor and CVA, this paper describes the important role of the CVA as part of the Continued Service Assessment team, the CVA activities and interfaces, as well as the varying degree of required independent oversight for different proposed continued service circumstances. This paper focuses on structure, marine systems, moorings and, to some degree, risers. Topside process or process safety are not discussed although there is an analogue process that is conducted as part of an overall Continued Service Assessment.
20ksi 350F High Pressure High Temperature Enhanced Vertical Deepwater Tree Development: Simplify, Eliminate, Integrate
Authors: Kirk Allison Weber , Mook Erik Van , Lusquinos Thiago , Keller Matthew 
Published: April 2018

Abstract
This paper presents the development of the first Enhanced Vertical Deepwater Tree (EVDT) system rated for 20 ksi pressure and 35° F to 350° F temperature applications. This project was a joint venture with five major operators. This system was designed and qualified to API 17TR8 and internal requirements.
The 20 ksi system design was a progression of 15 ksi and 400° F development, therefore many components are common between the 15 ksi and 400° F system and the 20 ksi and 350° F system. The 20 ksi design reduces cost as compared to a traditional EVDT by utilizing methods of simplification, elimination, and integration without compromising functionality. The scope of this development included materials testing and qualification, elastomeric seals, metallic seals, gaskets, bolted flanges, a new family of gate valves and actuators, tubing hanger, tree components, and a series of connectors.
This was a four-year development project which included component design, Failure Mode Effect and Criticality Assessment (FMECA), prototype testing, validation testing, meetings with BSEE, and independent third party reviews of technical documentation.
Umbilical Cost Reduction and System Availability Improvement with Use of Chemical Injection Valves
Authors: Campos Murilo , Silva Simao , Smith Matthew 
Published: April 2018

Abstract
Including chemical injection valves (CIVs), also known as chemical-injection throttle valves (CTVs), in subsea architectures can provide significant cost savings during the field development phase, while improving overall system availability over the design life.
CTVs can create economic and operational benefits for multi-well developments by reducing the number of chemical injection tubes required in the umbilical. Subsea wells often require chemical injection into the production fluid to inhibit scale, corrosion, asphaltene, or hydrate formation that can compromise the flowline integrity and impact or impede production. Chemicals are conveyed from the host facility through small-diameter stainless steel tubes that are bundled in the umbilical, which can also include hydraulic, electric power, and communication lines. Traditional oil and gas fielddesigns call for a dedicated tube for each treatment injection point, which typically ranges from two to four per subsea tree, depending on the flow assurance requirements. CTVs precisely control chemical flow rate at the point of injection, thereby allowing a single chemical tube to serve multiple injection points. This reduces capital expense and enables longer tiebacks.
The tubes in an umbilical make up to 80% of the cost of that unit. The reduction in the quantity of chemical injection tubes can allow the operator to adopt a more robust spares philosophy for the remaining tubes, and, since CTVs can be easily replaced by the use of a remotely operated vehicle (ROV)support vessel, the resulting system can have significantly greater overall availability over the service life.
CTVs can also be applied in brownfield applications to restore chemical injection to the wells after tube blockage and enable field expansion without installing new umbilicals.
Vortex-Induced Vibration Effects of Production Risers in Proximity with Drilling Risers or Tendons
Authors: Allen Don W. , Liu Nicole 
Published: April 2018

Abstract
This paper examines the effects of ocean currents on the vortex-induced vibration response of deepwater tubulars, such as umbilicals, production risers, tendons, and drilling risers, in proximity. This issue has received very little attention by the industry yet potentially has substantial importance to the design of deepwater tubulars and platforms.
Experiments have been conducted in a current flume on tandem flexible tubulars with diameter ratios of 2:1 and 4:1. The smaller diameter tubular was placed in both the upstream and downstream positions, with the top and bottom locations spaced apart at three different distances. The tension was kept constant, but the current speed was varied. While both uniform flow and sheared flow tests were conducted, only the uniform flow tests are reported herein.
The response modes varied from about 1-6, so that they were sufficiently high to easily allow both single mode and multiple mode responses, of which both were prevalent throughout the testing program. While all of the tests were conducted at low Reynolds numbers, the results can be thoughtfully translated to most field applications.
The results describe the vibration and response characteristics of both the upstream and downstream tubulars for various configurations that were tested. Since a myriad of diameter ratios, separation distances, and flow velocities are possible with tubulars in the field, these tests have attempted to provide general insights into the responses of tandem tubulars with unequal diameters and, in some cases, offer guidance on limitations to the responses that can be used for offshore field designs.
Baldpate Integrity Management Plan: A Continued Service Case Study
Authors: Kitson M. , Ramsay D. , Kemp D. , Moslehy Y. , Sheppard R. 
Published: April 2018

An effective Structural Integrity Management (SIM) program allows operators to manage structural risks and reduce the need for hazardous and costly underwater interventions. Inspection and operating decisions and costs are significantly affected by the SIM program definition and execution. This is particularly true for unique, deepwater assets like the Baldpate compliant tower, which features an innovative structural system and is among the tallest structures ever built. This valuable deepwater asset requires a well-executed SIM program to provide confidence that continued service and potentially expanded operations can be safely achieved.
Earlier studies had shown that fatigue sensitivities at critical locations could potentially limit Baldpate's useful life beyond the original 20 year target. In order to better understand the characteristics of this unique structure, a series of reassessment analyses were performed. These showed that fatigue sensitivities are not limiting factors for continued service of Baldpate, and the areas of fatigue sensitivity were incorporated into a long term SIM plan to focus future inspections and monitoring efforts. This paper provides details on the challenges facing the execution of the SIM plan, including benchmarking and verification performed for the Baldpate structure using field measurements, implementation of a real-time monitoring system, and targeted underwater inspections.
The dynamic behavior of axial tube guides, modeled using gap elements and surface friction, was identified as one of the more critical objectives to be addressed in the SIM plan. This posed a challenge since previous design and assessment efforts did not consider these components critical for global response. SIM options for these components were included in the plan, such as underwater inspections and on-site dynamic motion recording to examine the potentially undesirable behavior of these components. Undertaking these tasks led to affirmation of the structural reassessment results and facilitated development of new SIM resources. In particular, benchmarking the monitoring system provided Baldpate with constant surveillance of its condition. This real-time monitoring plan measures the dynamic characteristics of the tower under different load conditions to indicate when certain unique structural characteristics (e.g., axial tube motion within the guides) would affect the fatigue life of critical joints in the Baldpate tower.
Hebron's Labor Empowerment Strategy – A Legacy of Success
Authors: Haddock J. 
Published: April 2018

The majority of the Hebron Platform construction and fabrication was performed in the Province of Newfoundland and Labrador (NL). The NL construction labor workforce is robust, capable and unencumbered by the diverse harsh environment throughout Atlantic Canada. The local labor technical skills have generally kept in step with technology. However the construction safety statistics available at the beginning of the project raised concerns. Special focus was placed on labor force engagement and safety culture to achieve a strong project safety performance.This paper will outline the strategy implemented by Hebron to ultimately execute one of the safest construction projects in NL's history. In so doing, the Hebron Project created a lasting legacy of perspective, inclusiveness and accountability.
An Evaluation of Shear Testing Guidance and the Effects of External and Operational Loading on Pipe Shearability Using the Finite Element Analysis FEA Method
Authors: Hoefler John A. 
Published: April 2018

Abstract

Objective/Scope
The paper will evaluate all current and future shearing requirements such as API TR1, API 16A, and 30 CFR 250 and utilize a Finite Element Analysis (FEA) approach to virtually shear pipe and examine the effects of individual parameters on shear pressure.

Methods, Procedures, Process
Standards, Regulations and test protocols will be reviewed and compared to create recommendations for planning a shear test. FEA will be used to analyze how individual and/or combination of variables effect shear pressure. A baseline analysis will be performed using actual material properties of a pipe sheared in a laboratory. Once a baseline analysis is performed, separate analyses will be performed to study the effects of external loads and environmental conditions. The variables studied will be: TensionCompressionBendingInternal pressure of drill pipeWellbore pressureOffset pipe
Analysis of variables using the finite element method will facilitate review of variables by eliminating variations if this experiment were conducted in a laboratory such as pipe dimensions and tolerances, pipe material properties, and wear of testing equipment. FEA comparison can be performed at a fraction of the cost of full scale laboratory testing. Understanding the variables may highlight potential operational or procedural limitations, and improve the shear verification process defined in §30CFR250.732(b).

Results, Observations and Conclusions
Understanding all the variables may help to drive future shear testing requirements and analyze whether current testing protocols are adequate and potentially avoid unsafe operating conditions. The report will clearly demonstrate the effects that external loading and environmental conditions have on pipe shearing. The report will summarize all the guidance contained in industry specifications and regulatory requirements and provide recommendations for testing for both current and future requirements.

Novel/ Additive Information
The FEA program to be used is Abaqus Explicit with damage model. Shear damage can be simulated by "turning elements off" once the stress/ strain value has reached a critical point. Using the same geometry and mesh will allow for a true comparison of what effect each loading condition has on the shear force.