bluuebunny/crossref_metadata_2025_split huggingface dataset:
Malikai Tension Leg Platform - Drilling Tender Vessel - Top Tension Riser Operations
Authors: Aramanadka Shankar Bhat , Yong Lewis , Kota Ravi , Jamal Sharizal A , Yeap Fabian 
Published: April 2018

Abstract
Malikai Project made a cost-driven decision to adopt the 2-body TLP-DTV configuration to Drill and Complete the Wells offshore. By opting for a Tender Assisted Drilling approach to drill and complete the Well instead of fabricating a permanent rig package, the project could save capital expenditure by building a comparatively smaller TLP. Also cost-driven, for the first time in the industry, the project decided to employ Single-Casing Combo Top-Tensioned Riser (SCTTR) technology as opposed to using the combination of Drilling Risers, and a separate Dual-Casing Production TTR. This is however with a caveat that wear accumulation during drilling needs to be managed and kept to a minimum.
Combining the above, the project team needed to manage TLP-DTV marine operations paying attention to station keeping performance required by the SCTTR whilst ensuring the hardware on TLP-DTV (e.g. hawser lines, mooring lines, Personnel Transfer Bridge etc.) is operating safely within their design limits and maximizing the uptime of the offshore activities.
To address the specific joint marine operations on TLP and DTV during the Tender Assisted TTR installation, Drilling and Wells Completion phase of the project, an interdisciplinary taskforce comprising the TTR team, Station keeping and Global Performance team, Wells and TLP Operations teams was created for a fully integrated and focused operational procedure. This procedure was aimed atmanaging and assuring TLP-DTV repositioning and station keeping activities which meet the above constraints/objectives, complete with operation decision organization, a clear communication protocol, and comprehensive decision flowcharts to handle all possible scenarios during the operation. An onshore support group located within the well operations team is tasked with monitoring and predicting (based on forecast weather) of the performance of the TLP-TAD system for safe and effective station-keeping performance. The TLP-DTV-TTR operations is built upon the basis that the integrated team is able to plan the TTR installation / Wells construction operations in advance using forecast weather as inputs to continuously simulate numerically TLP-DTV performance - checking against repositioning criteria, as well as the continuous real-time monitoring of TLP-DTV performance against their operating windows using live data obtained from the MIS/MAS system (performed by both the Onshore team and Offshore team). Lastly, to ensure the overall effectiveness and accuracy in executing the operations, the team had created a suite of purpose-designed software to streamline the activities performed by the Onshore and Offshore Team respectively i.e. advanced activity planning via automated continuous forecast simulations of TLP-DTV and TTR performance to indicate operations go/no-go, as well as clear displays of key parameters constantly updated with live real-time data for operations monitoring.
Case Study: Deepwater Design Verification and Validation Testing for Subsurface Safety Valves for HPHT Environments
Authors: Thai Dan , Orzechowski Diana , Pinard Geoffrey , Henry Jason , Kaminski Dennis , Dighe Sourabh 
Published: April 2018

Abstract
The evolution of subsurface safety valve design for HPHT application has created the need for advanced design verification and validation testing to ensure "fit-for-service" application in a HPHT environment. With the release of API 14A 12th edition and the new V-1H validation grade, couple with Annex H for verification and validation requirements for high-pressure, high temperature environment, strenuous validation testing is required. Navigating the requirements can be difficult with the divergence from API 14A 11th Edition, Class 1, 2, 3, & 4 classes of service, to API 14A 12th Edition, V4-1 to V1-H. In addition to the validation grades, specialized Annexes (D, G, H, J, and L) requires collaboration between the Operator, with its functional specifications, and the service company to develop a specific design verification and validation testing program for Subsurface Safety Valves suitable for HPHT application.
This paper specifies a "fit-for-service" verification and validation plan conducted collaboratively by an Operator and Supplier. The validation testing plan outlines the requirement for V1-H validation grade along with required API 14A Annex testing. The paper also includes details on metallic component analysis using finite element analysis (FEA) and current ASME BPVC Section VIII using true-stress true-strain curves for accurate verification of the equipment design. Localized stress discontinuities and plastic localized yielding design criteria were also used to determine adequate protection against these failure modes, or if additional analysis is required.
With increasing regulatory oversight in HPHT technology development, product qualification planning requires in-depth knowledge of the designs and the criticality of the Subsurface Safety Valve as a critical barrier component. The Supplier and an Operator would like to share their experience and lessons-learned with the industry that would enable industry engineers to understand the requirements of design verification and validation testing of Subsurface Safety Valves for "fit-for-service" in a HPHT environment.
Search for MH370: New Geologic Insights Revealed through the Integration of Multiple Geophysical Datasets
Authors: McBee J. , Ingle S. , Gharib J. , McConnell D. 
Published: April 2018

During the search for the missing Malaysian Airlines Flight 370 (MH370), Fugro acquired the largest extent of high-resolution bathymetry in the southern Indian Ocean to date. Integration of these recently released multibeam echosounder (MBES) backscatter, bathymetry, water column, and sub-bottom profiler (SBP) data reveal additional insights into the characteristics of the Indian Ocean seafloor and the geologic and oceanographic processes that shaped it.
From June 2014 to February 2017, the M/V Fugro Equator, the M/V Fugro Supporter, and to a lesser extent, others, collected MBES and sub-bottom data over 710,000 square kilometers in the search area and along transit lines using Kongsberg EM122 MBES systems. We use Fledermaus GeoCoder to process backscatter data, and ArcGIS to create mosaics of all survey lines. Kingdom SMT is used to interpret SBP data. Water column data are interpreted in Fledermaus Midwater. Fledermaus is then used to create a 3D representation of the dataset.
In this presentation, we will highlight several prominent regional seafloor features, and illustrate insights gained by integrating MBES backscatter and water column data with bathymetric analyses. Backscatter data to the north of the southern flank of Broken Ridge illustrate the complexity to which sediment has been reworked downslope where intricate patterns of low backscatter intensities are observed. Here, exposed rocks form prominent high backscatter reflectors amid the surrounding low backscatter sediments. The lateral extent of high backscatter intensity reflectors south of the Diamantina reveals the expansiveness of exposed igneous rocks that resulted from seafloor spreading. Volcanic features, including off-axis volcanoes and leaky transforms are also interpreted as high backscatter anomalies in the tectonic spreading fabric to the north of the Geelvinck fracture zone, towards the southern extent of the dataset.
These examples show that by integrating the entire suite of data collected by MBES and SBP systems, more detailed interpretations of the geologic processes that shaped the seafloor may be gained than by examination of bathymetry alone.
A New Correlation for Predicting Solid Particle Erosion Caused by Gas-Sand Flow in Elbows
Authors: Parsi Mazdak , Arabnejad Hadi , Al-Sarkhi Abdelsalam , Zahedi Peyman , Vieira Ronald E. , Sharma Partha , McLaury Brenton S. 
Published: April 2018

Abstract
The current work presents a new correlation for estimating solid particle erosion under gas-sand flow conditions in standard elbows. To develop this correlation, in the first step, a dimensional analysis was performed to obtain dimensionless groups that governed the erosion phenomenon in standard elbows. Then, a power-law correlation was established among the extracted governing dimensionless groups. In the next step, effect of target wall material on erosion was investigated to include a material factor in the correlation. In the final step, an empirical factor to account for sand particle shape was included in the correlation.
Dimensionless erosion number was calculated for different flow conditions, sand sizes and densities, and pipe diameters. It was shown that the dimensionless groups and their exponents provide insight into the importance of different parameters on erosion. The resulting erosion ratio (in mm/kg) was compared to experimental data collected from the literature. It was found that the dimensionless erosion number correlation follows the trend of the experimental data, and good agreement between the correlation's predictions and the experimental data was observed.
The proposed correlation is an effective tool that enables the users to estimate erosion under gas-sand flow conditions in just several minutes. More importantly, unlike the existing empirical correlations that do not account for many of the parameters affecting erosion and have been developed based on a limited number of experimental data, the correlation proposed accounts for all flow and particle parameters.
Normalized Modulus Reduction and Damping Ratio Curves for Bay of Campeche Carbonate Sand
Authors: Flores Lopez F. A. , Taboada V. M. , Gonzalez Ramirez Z. X. , Cruz Roque D. , Barrera Nabor P. , Dantal V. S. 
Published: April 2018

Abstract
Predictive equations of normalized shear modulus (G/Gmax) and material damping ratio (D) are presented for calcareous sand, siliceous carbonate sand and carbonate sand of the Bay of Campeche and Tabasco Coastline. This was achieved using a database of 84 resonant column tests and 252 strain-controlled cyclic direct simple shear test that provide data to define the normalized shear modulus, G/Gmax, and material damping ratio, D, versus cyclic shear strain. The range of cyclic shear strains of the database is from 0.0001% to 1%, and the range of carbonate content (Ca2CO3) from 10% to 100%. The curves of normalized modulus reduction and damping ratio were organized in three groups according to the percentage of carbonate content: 1) calcareous sands (10% to 50%), 2) siliceous carbonate sand (50% to 90%) and 3) carbonate sands (90% to 100%). Two independent modified hyperbolic relations for normalized modulus reduction and material damping ratio versus cyclic shear strain were developed for each group. The normalized shear modulus was modeled using two parameters: 1) a reference strain defined as the strain at which G/Gmax is equal to 0.5, and 2) a parameter that controls the curvature of the normalized modulus reduction curve. The material damping ratio was modeled using four parameters: 1) a reference strain γrD defined as the strain at which D/Dmax= 0.5, 2) a curvature parameter αD that controls the curvature of the material damping ratio curve, 3) a maximum material damping ratio Dmax, and 4) a minimum material damping ratio Dmin. The new empirical relationships to predict the normalized modulus reduction and material damping ratio curves as a function of effective confining pressure are easy to apply in practice and can be used when site-specific dynamic laboratory testing is not available. The curves of G/Gmax-γ and D-γ, are similar between silica sand and calcareous sand. The curves of siliceous carbonate sand and carbonate sand are very similar, but show a different shape and width than the curves of silica sand and calcareous sand. This indicates that when the carbonate content is smaller than 50% there is a small effect on the curves of G/Gmax-γ and D-γ, and a considerable effect when the carbonate content is greater than 50%.
Cost Optimized Solutions for Near Shore FLNG
Authors: Kim CN , Hwang HW , Kim SE , Park SM , Park JS , Kim TJ , Kim YR , Kim YH 
Published: April 2018

AbstractOffshore development project are facing significant challenges from current market environment. Due to current low price of oil and gas, the development of natural reservoirs on offshore may not be attractive. However, the demand of natural gas will gradually increase because natural gas is relatively clean source comparing to the other fossil fuels and the demand of clean energy is growing due to environmental change.In this regards, Near Shore FLNG is becoming one of the most economical solutions as the unit is equipped with essential liquefaction process, storage as well as offloading facility. That is, comparing to typical deepwater FLNG application, expensive components are not required such as the turret, complex pre-treatment system and self-generation of utilities, plus logistics such as refrigerant supply are better.The purpose of this paper is to introduce the optimized process of Nearshore FLNG system comparing typical FLNG. To illustrate the optimized process, at first, target area is defined as North America. The reason why North America is selected is because of the potential of future projects and shale gas revolution. The gas composition is defined by reviewing 1,200 shale gas reservoirs in North America and considering the hydrocarbon gas is typical pipeline gas which needs to meet Pipeline Gas Spec requirement. Topside process is reviewed to find optimized options and process model has been built to check feasibility. Analysis is made on several technical optimized options as below. Optimized Liquefaction systemOptimized Condensate SystemRemove Deethanizer and Ethane make up columnOptimized Heating Medium systemOptimized Produced Water Treatment SystemFinally, this paper provides several options with reducing several facilities and optimizing process which will reduce CAPEX/OPEX.
Preventing Unexpected Walking Induced by Interaction Between Acceptable Uncontrolled Buckles And Spans
Authors: Verdeil Julien , Mourad Romain 
Published: April 2018

Abstract
The design of a long gas flowline laid on a rough seabed and in which HP/HT gas is circulating shows that the numerous spans along the line were all acceptable and that some acceptable lateral buckles will occur at some key features (crests).
A long section of the line was expected to be anchored preventing any walking. A first analysis with the steepest P/T transients showed no walking behaviour of the line. However it was observed that, when the line is gradually heated to the highest HT/HP profiles, unacceptable walking is observed at hot end. This paper will present how this line was designed and how an effective mitigation design was performed to prevent unacceptable walking and how that was implemented at the appropriate time in the overall design process.
Design activities were performed with non-linear finite-element software able to model the pipeline and its interaction with the rough seabed. The standard design activities were done, specifically; on-bottom roughness, lateral buckling analyses and their conclusions combined at the end of the design process into a global model built to simulate potential interaction between buckles and spans. This is a stepped process that should be followed in any pipeline design activities.
All spans and all potential rogue buckles were found acceptable, and the steepest HP/HT transients did not induce walking behaviour, as per conclusions from preliminary engineering studies. However, combining the most severe HP/HT scenario (corresponding to restart of the wells one after another) found spans along the line and the most probable scenario for locations of buckles led to unacceptable walking at hot end. This phenomenon is explained by the interaction between buckles and spans, as they evolve with the applied loadings. Mitigating this walking was achieved by integrating a padeye in the end structure. This particular padeye was linked by a chain to a single suction pile installed nearby. The integration of the mitigating padeye was done without any interruption to the overall schedule. This was achieved by an effective design process which listed the Key Interface Datas (KIDs) which in turn defines the important milestones between engineering disciplines (pipeline, structure, installation, fabrication).
There is no one single scenario that can lead to pipeline walking, particularly for lines laid on rough seabed with many spans and buckles. It is recommended to always study a case where several cycles of maximum operational profiles are applied. The overall design process should also list the Key Interface Datas in the overall schedule in order to ease the interfaces between engineering disciplines.
Malikai TLP - Superlift and Integration of Topside with Hull
Authors: Sinha S. K. , Zin Chuah Siak , Lim John , Walters Paul 
Published: April 2018

Lifting a heavy topside (superlift) for the integration with the Hull has always been a challenge for any mega project. Methods of lifting, skidding, lowering down for integration and final load distribution must be carefully studied before selecting the best possible method. Once the method has been determined, and the relevant procedures have been developed, the execution must then be strictly done in accordance of the procedures to meet the set objectives for the selected method.
The superlift and integration method must be determined at an early stage of the project, considering all aspects of engineering, procurement, installation, construction, post installation removal, contingencies, safety, scheduling, etc. for the project. This decision of selection is often a challenge, which will be discussed in this paper. All aspects including the above and the risks involved in each of them must be considered and mitigated.
This paper presents the super lift and integration method used for the Malikai Tension Leg Platform (TLP), highlighting the salient engineering characteristics of the specific method used.
For superlifting the Malikai TLP Topside, the Hull was completely integrated and both the Hull and the Topside were weighed. The Topside was then moved close to Hull, superlifted and then skidded above the Hull, alighted to the deck post and then finally lowered, to be integrated with the Hull. The operations involved heavy planning and interface with the superlift subcontractor, engineering, fabrication team, vendors and regulatory bodies. Various challenges were faced where the Topside of approx. 14,000 MT was lifted and integrated with the hull which will be outlined/discussed in the paper.
The superlift and integration which took approximately 9 days, finally resulted in safe integration of the TLP as planned with necessary design, construction and operational contingencies. The method included jacking up the Malikai Topside 40m high, before skidding the Topside 90 m whilst at this elevation - making this the world's highest jack-up and skidding operation performed on this scale.
Hybrid Subsea Foundation for Deepwater FLET: A Case History
Authors: Won Jeong-Yun , Audibert Jean M. E. , Misra Asutosh , Bush Samantha 
Published: April 2018

Abstract
In a recent Gulf of Mexico deepwater development project, two hybrid subsea foundations (HSF) were designed, fabricated and successfully installed for two flowline end terminations (FLETs) in approximately 2,170 meter water depth. The HSF is an attractive option when a subsea structure is subjected to substantial lateral loads, vertical loads and overturning moments that cannot be effectively resisted by a typical shallow (mudmat) foundation. A new HSF design methodology was established and a pile head locking system was developed by the project team. This is the first offshore application of the HSF concept utilizing the vertical resistance from the corner piles in addition to their lateral resistance via a custom designed pile head locking system. In configuring the pile head locking system to provide pile head fixity, the gap between the sleeve and the pile became one of the governing factors for design, fabrication and installation of the HSF. This paper presents the case history of the successful project execution covering the detailed design, fabrication and staged installation. Foundation selection during the detailed design stage, description of the pile locking system, preventive measures taken during the fabrication stage, back analysis results from the installation stages and pictures taken by remotely operated vehicles (ROVs) during the FLET HSF installation are presented.
Integrating Completions for a True Spud to First Oil Deepwater Well Manufacturing Machine
Authors: Wijning D. , Adams E. 
Published: April 2018

The concept of a deepwater well manufacturing machine, defining the next generation drillship design, provides a blank canvas for the pre-commissioned integration and deployment of complex subsea completion systems. Input from operators and third-party service providers on future deepwater well requirements enables the scientifically driven pre-positioning of the entire completions package, including tubulars, allowing for seamless transition from drilling to completions to safely and predictably reduce well delivery times, from spud to initiation of production.
This paper discusses step-change advances designed in an evolving concept to facilitate efficient running of deepwater completions, including offline handling of subsea completion equipment and XT's, while reducing logistical requirements. The authors will examine the flexible base of design, which comprises a flat and unobstructed work deck on the entire vessel, and replacement of the derrick and substructure with a Dual Multi-Purpose Tower (DMPT), incorporating robotic pipe manipulators and a 1,800ST hoisting system. An examination of current methodologies and future deepwater well designs provides insight into improvement opportunities, including applicable design of new or modified completions equipment.
The robotized DMPT in combination with a large, flat deck empowered the conception of new methodologies for handling and running subsea completion equipment and consumables, including cutting-edge drilling/completion fluid system and delivery capabilities. The modularized tower, robotized pipe grippers, tools, dual rotating setbacks and other unique components can be quickly and safely employed to optimize efficiency and safety throughout the completions process. Tubing can be racked in the setback drums in up to 180-ft stands, while more delicate and non-standard assemblies can be hung off at convenient elevations. The manipulators, with various dedicated tools, allow semi-automated running in hole. Furthermore, with a drill floor flush with the deck and absent V-door limitations, bulky equipment can be rigged up offline and easily skidded to the well center when required. When running tubing, a modular raised and skiddable work floor facilitates attachment of control lines and umbilicals below the hang-off table. Strategically located utility stations on the deck allow plug-and-play connections for power, air, communications and data transfer for third-party equipment, thereby reducing rig-up and rig-down time. Ultimately, these and other advancements have the potential to reduce by 20-30% the days required to complete a deepwater well.
By evaluating future deepwater well requirements, an optimal layout can be achieved at the onset. The vessel can be commissioned with all the proper tie-in points and a deck uncluttered with high-pressure pipe lines, cabling, separate diesel generators and the like. Provisions for ensuring tubulars are hung off so as to remain heave compensated at all times are also conceived and will be presented.