bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Safe and Cost Effective Diverless Method for Hull Wetted Surface Side Shell Repairs Executed On FPSO Fluminense
Authors: Webb Carl Michael , Sarabi Aidin , Constantinis Daniel Alexander , Anthony Travis Harley 
Published: August 2021

Abstract
The Bijupira and Salema oil fields in the Campos Basin, Brazil, are tied-back to the FPSO Fluminense. The design life of FPSO Fluminense was 15 years, first oil was in 2003. In 2017, Shell as operator and partner Petrobras decided to execute a 5 year life extension project to extend production until 2023. Although the life extension project encompassed many vessel, moorings, and production facility renovation projects, this paper will focus on the repairs of cracks in the wetted surfaces of the hull.
Crack repairs were executed during production operations using a novel methodology designed to eliminate the risks of diving operations, while significantly reducing the costs of the offshore hull repairs.
Earlier attempts using traditional methods with divers to deploy cofferdams were unsuccessful due to the high safety risk of diving in the persistent 2-plus knot Brazil current. In early 2019, the operator and a team of engineering consultants concluded that a novel repair approach that eliminates diving operations was feasible.
The concept methodology was developed, one element of which included positioning and securing a cofferdam over a cracked area of the FPSO side shell. The cofferdam was lowered from the FPSO deck while being guided into position and secured in place by guide wires passed through holes in the side shell. Water ingress into the void spaces was eliminated via a hot tap and winching system that penetrates the side shell from inside the tank.
Following the concept development, a step-by-step procedure was written, vetted with the classification society and subsequently used in the tendering process to select an execution contractor.
The selected execution contractor constructed a test tank that replicated the actual hull structure. The prototype was used to test the method at full scale, including procedures, communication protocols, and equipment. The learnings were incorporated into both the procedures and equipment. This process was repeated as a training exercise for the offshore personnel and HSSE leaders prior to offshore execution.
The execution contractor was mobilized offshore in the first quarter of 2020 and successfully performed the hull repairs. The job was completed as planned, including removal and replacement of several independent sections of stiffened hull plating, which included both flat and curved surfaces.
Based upon successful execution, this method has been proven to be a technology that can be used to eliminate the risks of diving and to significantly reduce the costs of future offshore hull repairs.
This paper will address the methodical approach taken to develop and integrate the various elements of this novel technology developed jointly by the operator and consultants, as well as the phases testing, pre-mobilization surveys, project execution, and other activities that drive success.
Improving Offshore Platform Production With Artificial Intelligence
Authors: Herve Philippe 
Published: August 2021

Abstract
The oil and gas sector is facing a changing market with new pressures to which it must learn to adapt. One of the biggest changes in expectations is the increased focus being placed on carbon emissions. Many consumers, investors, and lawmakers see reforms to the oil and gas industry as one of the most important avenues toward reducing carbon emissions and curbing climate change, and accordingly, a large number of companies have already made ambitious pledges towards carbon neutrality.
New technologies may offer the best avenue for oil and gas companies to reduce their carbon emissions and meet those neutrality goals. Digital technologies—and in particular, artificial intelligence—can aid in decarbonization even with relatively small investments, primarily by enabling large increases in efficiency and reducing unscheduled downtime and the need for flaring. This paper discusses how artificial intelligence-powered predictive maintenance can be applied to reduce carbon emissions, and a case study illustrating a real-world deployment of this technology.
Lost Circulation Risk Mitigation in Deepwater Cementing Operations with a New Tailored Spacer System
Authors: Gorman Angela , Patil Sandip , Agapiou Kyriacos 
Published: August 2021

Abstract
Lost circulation (LC), commonly encountered in drilling and cementing operations, can be a costly problem that increases non-productive time, especially in highly permeable formations. When LC occurs during cementing, zonal isolation can be compromised. Risks associated with LC affect most applications, including offshore operations. This paper presents the evaluation of a new tailored spacer system (TSS) designed to effectively mitigate LC and its use in deepwater cementing operations to meet zonal isolation objectives.
Development and Deployment of the Surface Current Imaging Nowcast System
Authors: Anderson P Steven , Zuckerman Seth , Stear James , Fan Shejun 
Published: August 2021

AbstractThis paper describes the development and installation of an ocean surface current monitoring device called SCINS: Surface Current Imaging Nowcast System. We describe the process of designing and building the prototype system, installation on an offshore platform, implementation of real-time reporting, and results from one year of operations.SCINS utilizes passive long-wave infrared imaging of the ocean to derive surface currents. This is done using a time-series of images to observe the phase-speed of the ocean waves. Then, the Doppler shift of the observed waves due to the surface current is determined using a non-linear least squares fit. The primary components of SCINS are a long-wave infrared camera and a data acquisition computer. The camera is mounted several 10s of m above the water surface. The system collects imagery at 2 Hz for 5 minutes every 15 minutes, day and night, and calculates surface currents in real-time.In this paper, we describe the results from deploying SCINS on an offshore platform, Chevron's Big Foot TLP, in the Gulf of Mexico for one year of continuous data collections, including several tropical storm and hurricane events. Results are compared to environmental data to describe system performance as a function of wind, wave, and sea conditions. We describe the engineering challenges and lessons learned from designing and installing this new type of passive imaging system for offshore use. We conclude that SCINS is an effective method for measuring surface currents in the vicinity of offshore platforms, requiring very little maintenance and without the need to put any instrumentation in the water.
Qualification of Barrier Fluidless, Sealless Seawater Canned Motor Pumps
Authors: Stover David L. , Pagani Christian 
Published: August 2021

Abstract
The oil and gas industry continues to push toward subsea pumping technologies that minimize required support systems and increase system reliability. Canned motor technology has been applied successfully in other applications to achieve similar objectives including driving a subsea twin-screw pump. Applied subsea, canned motors eliminate the need for any barrier fluids within the motor, the myriad of systems and complexities necessary to store and replenish these fluids, and the mechanical shaft seals required to prevent the leaking and/or contamination of these fluids within the motors.
As a direct adaptation of proven applications, see Figure 1, subsea water treatment is ideal for canned motor technology. Therefore, a development has been initiated and environment qualification testing of the first truly barrier fluidless, sealless subsea pump solution is complete.
This purpose of the paper is to highlight the novel elements of this technology, review the system configuration, and document the system performance in accordance with the TRL 4 qualification initiative.
Feasibility of the Potential for Wave and Wind Energy Hybrid Farm to Supply Offshore Oil Platform in Gulf of Mexico
Authors: Gu Chengcheng , Li Hua , Haces-Fernandez Francisco 
Published: August 2021

Abstract
Offshore oil and gas platforms use gas turbine with natural gas or fuel diesel for their high demand of power. Due to the declining amount of gas available, high carbon footprint, increasing cost of fuel and inefficient operating, alternative energy options are necessary and imminent. Most offshore oil and gas platforms locate in deep water surrounded by huge amount of energetic wave resources, hence, the feasibility of supplying offshore oil facilities electricity by hybrid wave and wind energy farms based on daily energy power production instead of annual average was conducted in this project. The hybrid energy farm was modeled and validated by applying meteorological data in Gulf of Mexico area from WaveWatch III system. With the hindcast wave and wind condition data from 1979 to 2019, daily energy generation of the hybrid energy farm was estimated. Meantime, the feasibility of suppling offshore oil and gas facilities by the proposed combined hybrid farm was assessed. The project optimized the configuration of the hybrid wave and wind energy farm to satisfy offshore oil and gas platform demands and reduce the variation of power generation, so that it may be feasibility to gradually substitute the gas turbines. Through matching the local wave and wind conditions, the project was able to maximize the power output while minimize the variation within limited ocean surface area. The project addressed the advantages of hybrid wave and wind devices, as well as theoretical prospection of wave harvesting device and wind turbine combination. To validate the proposed optimization model, a case study was explored by using Vesta V90 3MW wind turbines and Pelamis 750kW wave energy converters to supply five offshore platforms in more than 45 m deep water areas. The results indicated the possibility of bringing wave energy into large commercial operation and utilization with minor investment and environmental impact.
Design of Large-Size Suction Embedded Plate Anchors for Permanent Mooring Systems in the Gulf of Mexico
Authors: Chen Jinbo , Heyl Caspar N. , Newlin Jason A. , Karayaka Metin 
Published: August 2021

Abstract
Suction embedded plate anchors (SEPLAs) are an economic solution for the mooring system of a floating production platform and have been deployed both in the Gulf of Mexico (GoM) and around the globe with excellent field performance records. The design of SEPLAs has gradually matured over the past two decades for conventional SEPLAs, but debates continue both in the industry and academia, e.g., on the function of the flap and the required keying. These design aspects become more critical for permanent mooring systems in the GoM where the anchors have to resist large mooring tensions from hurricanes, and balancing safety and economy is a challenge. Thus, the objective of this paper is to present design considerations for large-size SEPLAs for permanent mooring systems in the GoM. The design considerations in this paper include the embedment loss, the functions of the flap and keying, cyclic loading, sustained loading, keying disturbance, and out-of-plane loading. Recommendations are provided to advance the design of large-size SEPLAs, and more specific guidance is offered relative to the ambiguous requirements currently in the industry guidelines.
Umbilical-Less Tubing Hanger Installation Controls System
Authors: Lovland Thor , Lokka Trond 
Published: August 2021

Abstract
The umbilical-less tubing hanger running installation tool, ROCS ("Remote Operated Control System") was first introduced as an R&D project to the market in early 2020. By February 2021, it is in operation for Aker BP in the North Sea on Deepsea Nordkapp.
ROCS is specifically designed to increase the robustness and efficiency of running the production tubing in the well. In a traditional operation, the Tubing Hanger Running Tool ("THRT") normally communicates topside through an umbilical. The ROCS eliminate the controls umbilical by having two methods of communication to the THRT, either acoustic or through wired pipe, preference is acoustic. This also eliminates the topside WorkOver Completion System ("WOCS"). The approximately 16meter long ROCS is also designed with a Ready To Run ("R2R") principle, where the ROCS, THRT and Tubing Hanger ("TH") is made ready on land for offshore operations, already connected and tested.
The system is redundant and based on a closed loop hydraulics, powered by a subsea HPU, electrically supplied from subsea batteries. The SHPU is small in size and power consumption, capable of providing the required flow at 690bar. The control functions occur through electrically held DCV's ("Directional Control Valve") for controlling all of the required TH functions. The ROCS is capable of performing 3 operations of each TH function within the allocated deployed period. The energy required is provided between the hydraulic accumulators and batteries. Pressure balanced accumulators are included to optimize all deepwater operations. A properly sized clean reservoir is installed, interfacing the pre charged accumulators. ROCS is controlled through a modular and user-friendly topside HMI ("Human Interface Machine"), communicating acoustically or through wired pipe over any type communication protocol.
The benefits include removing personnel from red zone, as well as eliminating time to clamp umbilical to the drillpipe. This significantly reduces mobilization of the system to a few hours, which also eliminates the topside deck space considerably. The running time is reduced and allows to increase speed of the drill pipe. This also reduces the risk of damaging production tubing or downhole equipment. There is no risk of downtime due to damaged conduit and the operating weather window is increased.
Case Study: The Impact of VR & AR Simulation Project to Decrease Human Exposure in Critical Environments
Authors: Reis Juan Ribeiro , de Oliveira Thiago Sousa , de Oliveira Wesley Lopes , Barboza Diego Cordeiro , De Melo Leonildes Soares , Oberziner André Luiz Bertoldi , da Silva Paulo Andrade 
Published: August 2021

Abstract
Human exposure is a relevant factor when operating in critical environments and depends on a thorough analysis and consideration towards driving the teams to a safer and more productive environment. Reducing such exposure through digital technologies benefits the whole workforce in their decisions and maneuvers, like simulations, training, and other critical activities that can be executed remotely and prior to the actual activity.
This paper presents a case study to demonstrate how augmented and virtual reality can be used to create a high fidelity virtual environment emulating the real industrial facility. This approach enriches the Digital Twin with the association of data and the virtual environment. It leverages on display and interaction capabilities of hardware devices, and intelligence and data querying capabilities of industrial software, empowering the workers with enhanced training capabilities and access to information increasing safety and efficiency.
A real application of this technology is presented in this paper through the case study of the PredictMain4.0 project of Repsol Sinopec Brazil (RSB), which aimed at the integration of digital technologies, including augmented reality (AR) and virtual reality (VR). The PredictMain4.0 project was executed using data and data models of PETROBRAS’ P-50, a FPSO (Floating Production Storage and Offloading) operating in Brazil, and illustrates how different AR/VR applications can be developed and used in combination with engineering, operation, and maintenance databases. This includes 3D models, digitalized critical procedures, and the ability to integrate field teams into a single virtual environment, allowing real interaction in a digital setting that is linked to the real world. Considering the digitalized procedures, this paper aims to establish how virtual simulation and training can make teams more confident and prepared to execute the same physical asset procedures.
After consulting with stakeholders from many different teams, the PredictMain4.0 project team selected three critical operating modules in the FPSO (Power Generation, Water Injection, and Gas Compression). For each one, considered which situations were relevant, should they occur. These situations led to developing a training and simulation framework, allowing instructors to create different scenarios and use advanced features such as digital measurement, real-time data collection, and collaborative sessions.
The case study indicates that the development of such applications can save more than $1 million per year in maintenance costs considering the decrease in downtime and avoiding risks of accident.
Normalized Modulus Reduction and Damping Ratio Curves for Bay of Campeche Calcareous Clay to Carbonate Mud
Authors: Taboada Victor Manuel , Cao Shuang Cindy , Flores Lopez Francisco Alonso , Cruz Roque Diego , Barrera Nabor Procoro 
Published: August 2021

Abstract
Equations to calculate the modulus reduction curve (G/Gmax-γ) and material damping ratio curve (D-γ) of calcareous clay and clayey carbonate mud of the Bay of Campeche and Tabasco Coastline are developed. This was achieved using a database of 156 resonant column tests and 468 strain-controlled cyclic direct simple shear tests performed in clays with 10 % ≤ CaCO3 ≤90 %. The effects of carbonate content (CaCO3), mean effective confining pressure (σ′m), plasticity index (PI), and overconsolidation ratio (OCR) on the shape of the modulus reduction and material damping ratio curves are shown based on the available laboratory data and the equations developed to calculate these curves. It is shown that as CaCO3 increases, the normalized shear modulus (G/Gmax) curve tends to shift downward and the damping ratio (D) curve tends to shift upward; as σ′m and PI increase, the G/Gmax curve tends to shift upward and the damping ratio curve tends to shift downward; and the value of OCR has practically no effect on the position of the curves. The validation of the calculated values of G/Gmax and D shows the best predictions are found at low shear strains for G/Gmax and at large shear strains for D, falling within ± 25 % of the measured values, and shows that due to limitations in the model at large strains (γ &gt; 1 %) for G/Gmax and at low strains (γ &lt; 0.05 %) for D, the calculated values fall within ± 50 % of the measured values. The equations developed to calculate the curves of G/Gmax-γ and D-γ of calcareous clay and clayey carbonate mud are recommended for preliminary or perhaps even final seismic site response evaluations. However, considering the scatter of the data points around the curves, the equations should be used with caution, and parametric and sensitivity studies are strongly recommended to assess the importance of this scatter. In large critical projects, direct experimental determinations of G/Gmax and D for the soils of interest are suggested to be more appropriate.
Sealing Advancements for Rotating Control Devices
Authors: Richie Aaron Paul , Dietle Lannie Laroy 
Published: August 2021

Abstract
Some of the most critical elements of a rotating control device (RCD) are the rotary seals that prevent a pressurized abrasive drilling fluid from destroying the rolling element bearings. The rotary seals prevent the drilling fluid from damaging the bearings by sealing the annular gap between the rotating mandrel and the stationary bearing housing. The combination of pressure causing seal material to bulge into the annular gap and the relative runout between the mandrel and housing can cause extrusion damage of the seal. The relative rotation and runout between the seal and mandrel in an abrasive environment leads to abrasive wear of the seal. Finally, the relatively high surface speed and contact pressure between the seal and mandrel leads to adhesive wear of the seal.
When the drilling fluid pressure below the RCD is low there are several suitable rotary seal designs that can provide acceptable RCD life at most rotary drilling speeds. To meet higher speed and pressure conditions for the 100 hour minimum duration, established in API 16RCD, many RCD designs employ a sealing approach that splits the sealing tasks across two seals. One seal excludes the abrasive drilling fluid at low differential pressure and another seal, capable of operating at high differential pressure, retains a clean lubricant that is at nearly the same pressure as the drilling fluid. This sealing system generally requires an external lubricant pressurization system to provide the necessary fluid and pressure environment for the seals. Some drilling sites that operate at these conditions cannot accommodate these large, complex, expensive lubricant systems due to space or access constraints, or economic considerations.
This paper describes an innovative sealing system that enables an RCD to operate at 1,500 psi and 100 RPM for 200 hours without requiring an external lubricant pressurization system. This claim is based on extensive laboratory testing of three new technologies included in this sealing system. Key results and summaries from the test program are included in this paper. The three key technologies are:
A hydrodynamic spring-loaded lip seal that can be used to exclude abrasive drilling fluid at low-differential pressure or retain a clean lubricant at high differential pressure. A direct-compression hydrodynamic seal that can retain a clean lubricant at high differential pressure. A self-actuating miniature valve that replaces the lubricant supply function of an external lubricant pressurization system.
Rams Analysis for Different XT Technologies
Authors: Glaser Markus , Winter Tobias 
Published: August 2021

Abstract
This paper analyses the probability of failure on demand of different subsea christmas tree actuation principles and their related control system architectures. The all-electric technology has limited or insufficient field data available. This means that the reliability and availability analysis is based on theoretical analysis from data provided in reliability handbooks for mechanical and electronic components. The analysis includes the probability of failure on demand to isolate the well and the availability of each equipment type until a first failure causes the need for repair. The following different actuator and system designs were chosen for this analysis:
– Spring based hydraulic actuator – Spring based electric actuator – Electric power screw actuator – Electric planetary roller screw actuator
All Electric Systems (except the spring based electric actuator) utilize a battery to provide the energy for the valve operation. The reliability analysis provides detailed information about the major contributors that limit the reliability of the actuators and systems. With this knowledge, qualification activities can focus on the improvement of the reliability of the critical components and the actuator elements within the system.
The power screw actuator and the corresponding system provides the best reliability and availability compared to other systems. The electric with spring design provides better results than the hydraulic with spring design. Generally, the battery-based systems provide a better reliability than spring-based designs.
The most critical elements are the mechanical springs, sealings, brakes and the spindle mechanisms.
Another aspect is the analysis of an optimized operation strategy in order to utilize the redundant components to improve the availability and reduce the number of interventions by analysis of the second and third failure in the system.