bluuebunny/crossref_metadata_2025_split huggingface dataset:
Impact of the Optimization Procedure on the Equation of State Regression
Authors: Fulchignoni Lívia Paiva , Tartakovsky Daniel M. 
Published: October 2023

Abstract
We investigate the impact of different optimization algorithms and initial guesses on the regression of an equation of state (EoS) for reservoir fluid models, using data for a reservoir fluid from the Brazilian pre-salt region. We employ four optimization strategies, including gradient-based and evolutionary techniques, combined with varied initial guesses to derive alternative regressed EoS models. Our results reveal that while the alternative regressed EoS models demonstrate similar levels of fit to the experimental data, their predictions for phase equilibria are markedly different. This highlights the sensitivity of the EoS regression to subjective choices of an optimization algorithm and an initial guess, and their implications for flow assurance and reservoir simulation and management.
New Method for Evaluating and Managing Reability of Drilling Rigs Critical Systems
Authors: Pereira Y. S. , Lukin N. , Rodrigues S. S. , da Costa P. R. V. 
Published: October 2023

Abstract
For the Performance Contract philosophy, evaluating performance is an essential part of aligning interests in contracted relationships. Furthermore, it allows for assessing the effectiveness of contracted initiatives, enhancing efficiency by fostering competitiveness and autonomy.
In the offshore drilling industry, NPT (Non-Productive Time) is commonly used as a metric for evaluating asset management performance. However, this indicator has many limitations that impact a robust evaluation of contractor and manufacturer management.
To increase the consistency of performance evaluation in drilling management, the initiative sought to expand the currently applied fleet management concepts through the application of Mean Time Between Failures (MTBF) and availability concepts. However, for an accurate diagnosis, it is necessary to individualize goals by critical system, so that each system receives a specific target to compare with fleet results. The drilling rigs and operators are then given a rating based on the weighting of system ratings. With structured data, the performance of different operators, manufacturers, and rig classes can be compared, revealing their strengths and improvement opportunities. Additionally, statistical analyses were used to identify significant variables, such as the intrinsic reliability of manufacturers.
Modular Casing Drilling Bits Design
Authors: Gómez Pedro José , Lafont Alejandro Federico 
Published: October 2023

Absract
The average drilling activity for the operator is between 150 and 200 wells per year in the Gulf of San Jorge Basin (Muzzio, J (2017)). The majority of these wells are vertical and target oil and gas production, as well as injection wells for the development of the Cerro Dragón mature field. The first casing drilling tests were conducted in 2008. Initially, BHAs combining casing with recoverable components were used. Due to the geological characteristics of the field, such as dips, fault presence, and rock geomechanical properties, complete casing assemblies with premium connections and specific bottom hole assembly configurations were developed. The shoe track, as well as the designs of the drill bits and pup joints, have played a crucial role in achieving high penetration rates (ROP) and, more importantly, meeting directional drilling targets.
The objective of this paper is to present how the operator applied a methodology of continuous tool development, evaluating and mitigating risks, which aims to provide greater agility for design iteration, challenging the status quo through collaboration with our suppliers.
The casing drilling method used, for the most part the wells, falls under the classification of Casing Drilling Level 2 (M. Makri, (2016)), which involves drilling a well with a non-retrievable bottom hole assembly. Within the development of drill bit designs for this methodology, major suppliers primarily focused on the development of drill bits with drillable materials in the bit head and integral connections. As the methodology and associated technological improvements progressed, the need for connections that included internal check valves and ports for auxiliary cementing arose, and the use of drillable materials in the drill bit head was deemed unnecessary. Additionally, the operation and progress in results required the use of more than one type of connection, both in terms of diameters and thread types.
FPSO Longitudinal Cargo Tank Arrangement
Authors: Costa Filho Fernando Homem 
Published: October 2023

Abstract
The use of floating production, storage, and offloading (FPSO) vessels for offshore oil production has been deemed the most effective solution, mainly for deep waters applications where they eliminate the need to lay an expensive long-distance pipeline to an onshore terminal. Another advantage is its storage capacity of up to fourteen days of total oil production. The cargo tanks are arranged below the ship deck in the hull to store this production. So far, the arrangement of the tanks is the same as used in oil tankers from which the FPSO design came. This paper presents a longitudinal cargo tank arrangement that aims to reduce the amount of equipment and piping on the FPSO deck. This longitudinal arrangement saves topside weight and space and reduces FPSO construction and commission time. Further benefits are achieved by reducing the cost of operating and maintaining the storage and offloading systems due to reducing the number of cargo pumps and piping.
FPSO Guanabara: How we Overtake and Manage Complex and Unpredictable Scenarios to Reach the FPSO TOP in 9 Months
Authors: Rocha V. T. da S. , Garcia F. C. , Almeida E. C. , Joao L. V. 
Published: October 2023

Abstract
Shipbuilding industry had been impacted by COVID pandemic on the last years. In order to keep project schedule, some innovative actions were implemented. The objective of this project is present how FPSO Guanabara found an alternative highly efficient way to follow-up the construction and commissioning completeness, as well as operational start-up readiness on Mero, pre-salt of Santos Basin, off coast Brazil.
FPSO construction, in normal conditions, is recognized as a very traditional activity, where stakeholders (Owner, Shipyards, Operator, Class Societies, etc) control the main issues, that means it is possible to predict delivery date and associated commissioning completion/carry over list. The COVID pandemic has changed the scenario bringing a lot of uncertainties to the project such as: government restrictions for foreigner entry countries - lack of owner and operator survey on constructions sites; slow manpower ramp-up; need to perform site remote inspections, class society changing inspections mode, etc. FPSO Guanabara construction has implemented some actions to overcome restrictions imposed by the pandemic scenario: change location of construction site to country with more flexible control rules regard to covid; use of Chinese Partners as Surveyors of Petrobras, with remote post analysis by experts; reprioritization of activities in order to enable systems offshore commissioning, take the Unit straight to location in order to mitigate Covid contamination at anchorage point in Brazil sheltered waters.
FPSO Guanabara started oil production on April/2022, three months after arrival on Mero Field, directly from Dubai Shipyard. Six months later, the FPSO production ramped up to 150,000 BPD. The top of production (180,000 BPD) was achieved on Jan/2023, after 9 months of starting production, with a trajectory of high efficiency (more than 95% of average) and environmental sustainability (low flaring).
The actions taken establish a successful guide on how to manage adverse situations on shipbuilding industry.
Design of Subsea Jumpers with Preliminary Field Layout
Authors: Barros P. , Porto T. , Valer C. I. 
Published: October 2023

Abstract
The objective of this work is to present a new methodology (called: ‘SafeOP’) for the design of subsea Rigid Jumpers (RJ) to assist the development of EPCI (Engineering, Procurement, Construction, and Installation) projects for submarine interconnection in Brazilian fields based on preliminary field layouts.
The new methodology is based on a more complete parametric study based on the layout of the field where there are limits given by the capacities of the pipes, connectors, or by the resistance of the well XT (Christmas Tree). The proposed flexibility of the arrangement is to analyze all possible configurations of a wellhead Rigid Jumper, between a first end PLET (Pipeline End Termination) and a XT, varying the angle between the Jumper and PLET heading, that is aligned with the Flowline. To be able to cover the spectrum of all connection possibilities between Jumper and Flowline and thus find an envelope for the positioning of the target boxes, which limits this angle according to the proposed geometry.
The results obtained with this methodology demonstrated to be very satisfactory, with great economy in the engineering executed on this type of design package.
The application of the methodology defines the angular limits where the arrangement works for the proposed field layout and thus, it will be possible to give greater flexibility due to the understanding of these limits and maximum angles where the design continues to be valid, even after changing the layout. This performed by simply checking the angle between the structures and updating the arrangement for the new angle and new lengths found.
This methodology is very important considering the detailed design of jumpers in an EPCI project is strongly linked to the geometry of the subsea field layout which may not be available at the early project stage. In addition, the design of the jumper involves interfaces with different project teams for activities, including preparation of specifications, procurement, fabrication, testing, assembly, loading, offshore transport, subsea installation, and commissioning of equipment. At the same time, due to schedule constraints, the design of jumpers cannot be carried out too late in the project, without delaying the interfacing activities.
As part of pre-salt developments offshore Brazil, the field layout may change significantly through the course of the project execution phase, to minimize the associated planning and financial risk for the project, the proposed approach allows decoupling of the rigid jumper design from the local field layout potential changes by defining beforehand associated working envelops for a full range of possible local field layout.
Long Tie Back Developments for Pre Salt
Authors: Laffray G. , Palermo T. , Fidel-Dufour A. , Pire M. , Snoussi W. 
Published: October 2023

Abstract
A study entitled "Long Subsea Tie-back Solutions for Pre-salt fields" was launched to compare different architectures concerning the hydrate and wax risks. In general, it aims the development of technical solutions and technologies applied to long subsea tie-back on pre-salt fields as a technically feasible and profitable solution. A fictive pre-salt field of two production wells located at 2,500m water depth tied back to a FPSO with a production flowline of around 30 km is considered.
This study started with a screening study to assess the technical feasibility of different "single line" concepts. A cost estimate study has been done in parallel to support the most cost-effective solution. Five architectures have been investigated: Two architectures without subsea processing: 1 trunkline;2 single lines.Two architectures with Subsea Separation Unit (SSU): SSU close to wells.SSU at riser base.One architecture with Multi Phase Pump (MPP) MPP close to wells.
At the end of this phase, only three architectures Trunkline, Riser Base SSU and MPP architectures have been retained as the most attractive ones in terms of operability and costs (as indicated in the Fig 1). The concept Subsea Separation Unit (SSU) located close to wells even if inducing low costs was not kept as difficult to operate within the production field life. The two single lines concept was not competitive compared to the trunkline one. Moreover, in terms of costs, a strong incentive has been demonstrated for "lighter" architecture concepts (i.e. a flowline thermal insulation of a wet insulated flowline compared to a Pipe in Pipe (PIP) flowline and without flowline heating system such as electrical trace heating with pipe in pipe insulation (ETH-PIP) technology).
State of the Art Pipeline Engineering Adopted for the BM-C-33 Offshore Export Pipeline
Authors: Nystrøm P. R. , Kristiansen N. Ø. , Gilbu E. J. , Lyngsaunet O. M. , Ilstad H. , Valeriano I. A. 
Published: October 2023

Abstract
The BM-C-33 gas export pipeline, with its dimension of 22/24"OD, is one of the deepest large-OD pipelines under development. The pipeline design at such water depth is pushing the boundaries of current design codes, line pipe manufacturing capabilities and available installation vessels in the market.
The purpose of this paper is to mainly focus on the key challenges and opportunities related to design, installation, and commissioning of the ultra-deep section of the BM-C-33 gas export pipeline route. Furthermore, it will outline associated mitigations that will be captured in the project development and execution phases.
Key challenges to be discussed in this paper are related to the ultra-deep end of the pipeline route includes high installation loads; wall thickness design considerations for high external pressure; large and complex pre-commissioning scope involving exploring using the REPLACE JIP methodology; PLEM design considerations; free span and thermal buckling mitigation strategies and route challenges.
Real-Time Monitoring and Diagnostics Applied to False Kick Detection
Authors: Oliveira L. A. , da Silva F. R. G. , Fonseca T. U. , Donatti C. N. , Carriço V. H. R. , Fasolin K. , Martins A. L. 
Published: October 2023

Abstract
Kicks are one of the main safety concerns in drilling operations, especially offshore, since they could lead to a blowout if not detected as soon it starts. Sometimes kick indicators can be smoothed and it might be difficult to determine if there is a real kick or another physical event taking place within the well. The fluid temperature effect might be misinterpreted as a kick migration, generates a false alarm, and stop operations until there is enough evidence that it is not a kick, due to the severe consequences that it can lead in a real occurrence. These thermal effects can be considered inherent to the operation, given that it is natural to deep wells reach higher temperatures in the subsurface and thus the fluid could experiment an expansion associated with an increase in pressure. The proposed calculation presented in this work acts in a way to reduce the time used to evaluate these specific situations in real-time and allows a safety operation resume. After development tests, the new false-kick module was included in a drilling digital twin software, currently in use by a drilling engineers’ team, on a 24×7 service inside the client Real-Time Operation Center (RTOC). While performing tests at the homologation server/database, the results were in agreement with the expectations, proving that around 40 minutes of rig time could be saved for each false kick detection. These results add value to the operations as it provides more sensitive information to be taken into account while evaluating a kick scenario and shortens the time frame reaction to deal with an inconclusive pressure/flow check. The novelty is the usage of a drilling digital twin to include a false kick analysis, enabling it to detect whether just a thermal effect occurred instead of a real kick. The numerical simulation already runs robust data monitoring, evaluating a big amount of data in real-time, and the new feature helps reducing operation risks to resume operations faster.
NADAH - New Approach of Design Against Hydrates
Authors: Candelier C. , Lesage N. , Saint Pierre T. 
Published: October 2023

Abstract
Hydrates, solid crystals looking like compact snow (gas system) or slurry (oil system), are formed of water and gas at high pressure and low temperature (Figure 1) [1]. These conditions are usually encountered during shutdowns and restart operations in deepwater environment.
Considering the associated production shortfalls and the cost of offshore remediation means, line blockage due to hydrates formation must be avoided [2]. And as a consequence, one of the main constraints in the design and operation of deepwater subsea developments has often been the management of hydrates in the production flowlines.
Using External Automated Ultrasonic Inspection (C-Scan) for Mapping Internal Corrosion on Offshore Caissons
Authors: Silva Arilson R. , Araujo Mauro D. 
Published: October 2023

Abstract
Caissons are typical large diameter and long length piping installed on FPSO (Floating, Production, Storage and Offloading) and oil platforms. Basically, the components of a Caisson system are a centralized pump inside a cylinder (shell) and generally operates with sea water. These Caissons are susceptible to wall thickness thinning caused by abrasion and corrosion [3] on the internal surfaces. This corrosion occurs due to internal coating damages caused by internal shell impacts of the decentralized pump parts, during the operating condition.
Detecting Caisson internal thinning is not a simple task once the thinned areas are localized, which can occur at any place on the internal surface, and it is a huge area to inspect since a Caisson can have tens of meters and a large diameter. For this reason, punctual/spot ultrasonic thickness (UT) measurements are not effective, as it requires a complete surface scan using an NDT technique sensitive enough, such as an UT C-Scan. Another benefit of this application is the unnecessity of scaffolding or rope access, reducing human exposition risks and costs.
The mapping and sizing accuracy was achieved using a robotic remote-controlled magnetic wheel automated robotic scanner. The scanner adhered to the pipe's external surface following X, Y coordinates defined by the NDT instruction and adjusted during the field inspection. The robotic system is a high-resolution equipment, achieving up to 1x1 mm resolution. Another important system characteristic is the maneuverability that allows reaching even the most difficult access areas.
The objective of this paper is to present the results of an external inspections on Caissons using Robotic Automated Ultrasonic (C-Scan) corrosion mapping for detecting and sizing internal thinning. This NDT was done without scaffolding and coating removal. Many localized thinned areas were found, mapped, and sized. These localized thinned areas would not have been detected using punctual thickness measurement.
The results of 20 Caisson walls inspection showed outstanding results locating all corroded areas and high precision defect sizing. All robotic inspections were faster and provided lower costs and less human exposition risks, when compared to the traditional thickness measurement method used before.
Implementation of a Multi-Technology Approach for Flexible Risers' Inspection - Improving Effectiveness and Efficiency
Authors: Vagata A. 
Published: October 2023

Abstract
Flexible risers are an important component of offshore production systems of oil and gas. They are used to link subsea pipelines to floating installations, such as FPSOs. Flexible risers have been one of the preferred deepwater riser solutions in many regions of the world due to their good dynamic behavior and reliability.
Flexible risers are multi-layered pipes typically comprising of an inner flexible metal carcass surrounded by polymer layers and spiral wound steel layers, also referred to as armor wires. The most common integrity issues relating to flexible risers are mechanical damage to the outer sheath or a venting system's failure. These can lead to a pressure breach of the out sheath and flooding of the riser annulus, ultimately weakening the riser integrity through corrosion of the internal wire. This paper discusses the motivation and business driver for developing and implementing new and cost-effective flexible risers' inspection methodologies based on a multi-technology approach that allows the assessment of the flooding status of the riser and the corrosion status of the internal steel layers. The paper is based upon worldwide flexible risers' inspection campaigns. The complex multi-layered structure which characterizes the flexible risers is not favorable for inspection with most non-destructive testing (NDT) techniques, which makes structural integrity evaluation difficult. Initial industry efforts concentrated on the search for a single technique which would ensure reliable detection of armor failure, but recent experiences have shown that the safest approach may be to take advantage of a Multi-Technology Approach obtained when different instruments are combined. Backbone of the new multi-technology approach presented is the use of a MEC (Magnetic Eddy Current) based subsea crawler that has the key advantage to rapidly scan large surfaces with or without coating and detect reliably internal wire defects. MEC is complemented by a frequency-based ultrasonic measurements system to assess the flooding status of the riser. For the assessment of specific issues, a CT (Computed Tomography) scanner is used to support the inspection. The inspection data are processed in real time for an immediate assessment of the integrity of the asset. The crawler is equipped also with an advanced cleaning and high-definition video system. Examples are presented, and comparison is made between traditional and new inspection methodologies based on recent flexible risers' inspection campaigns to demonstrate the improvement of inspection effectiveness and efficiency.