bluuebunny/crossref_metadata_2025_split huggingface dataset:
Digitally Transforming Offshore Production: Making Low-Manned Brownfield Installations a Reality
Authors: LaGrange Elgonda , Bollinger Brett , Elnaamani Ali 
Published: August 2021

Abstract
This paper outlines an approach for de-manning brownfield offshore production installations. It discusses how the latest advancements in rotating equipment, electrical & automation systems, and digitalization can be applied to reduce operating costs, lower breakeven prices, and extend the lifetime of existing/aging fields.
The approach is value-rather than technology-driven and focuses on prioritizing investments based on return on investment (ROI) to enable low-manned operations as a stepping-stone towards unmanned installations. The paper discusses key facets of a holistic de-manning strategy, including:
Remotely controlled production operations Predictive analytics to reduce unplanned downtime and extend mean time between overhauls (MTBO) Automated inspections Remote collaboration Unified data management Change management
The concepts presented in the paper are derived from the authors’ company's work implementing digital solutions for customers in both onshore and offshore oil and gas, and power generation industries. It also draws on the results of an in-depth onshore field de-manning study that was conducted for a major Middle East national oil company (NOC).
Driving Superior Performance in Brazilian Pre-Salt - The Challenges, Solutions and Achievements of Shell and Providers in Exploratory Pre-Salt Wells in Brazil
Authors: Barrios Enrique , Santos Rafael , Hartmann Robin , Pessanha Vinícius , Neves Romulo Adrien , Pereira Rodrigo Alves , Ribeiro Rodrigo Rodrigues , Schimmelpfennig Thiago 
Published: August 2021

Abstract
The Brazilian Pre-Salt has gained importance as an essential world-class province given its prolific production and thanks to its many challenges, it has incentivized the market to look for better ways to faces these technical challenges safely. This article aims to describe the main challenges faced by Shell and Constellation as well as the approach adopted to improve the operations’ safety and reduce drilling time, significantly reducing the drilling costs in an exploratory campaign in the Brazilian Pre-Salt.
The campaign was based on the buildup of a partnership between the drilling contractor, operator and the main services provider, Halliburton, creating a transparent and collaborative environment, which improved all parties’ ownership and accountability. The application of many processes and techniques such as Step Seven, Stop Work Authority and Design of Work improved safety and efficiency. A precise equipment selection, detailed planning and careful execution with disciplined application of a learning mindset were also paramount to drilling performance.
Four pre-salt wells were drilled in the campaign at Sul de Gato de Mato (2 wells), Alto de Cabo Frio and Saturno prospects with all of them qualifying in terms of drilling time as best in class (BIC), i.e., within the top 5% percentile. In 2019, the GdM3 well was the fastest delivery of a pre-salt well out of the 250+ wells in the region. The well GdM4 drilled in 2020 as part of the same campaign broke the previous record by seven days, being the fastest pre-salt well ever drilled with its 18 dry hole days mark.
The main reason associated with the campaign´s success was the utilization of the DID-PDCA methodology, which promoted the integration of all the workforce in a cycle towards continuous improvement by: (i) carefully selecting the equipment and experienced service providers, (ii) generating detailed plans of the drilling activity and engaging all those involved in the delivery, (iii) establishing and applying a HSE strategy for safety culture enhanced and (iv) constantly monitoring of performance and discussing the next steps.
Along this article a summary of well layout, the drilling phase duration, some of the key performance improvement initiatives as well as how they were generated will be shared.
Energetics and Kinematics of Inertial Oscillations in the Central Northern GOM
Authors: Ivanov Leonid , Ramos Rafael , Gustafson Drew 
Published: August 2021

Abstract
Understanding the physics of generation, propagation, and dissipation of inertial currents is important from a variety of aspects. For the Gulf of Mexico, one such aspect is that these oscillations represent an uncertainty in the measurements and forecasting of the longer-period currents, such as those due to the Loop Current (LC) and meso-scale eddies. The Industry has a practice of applying an ‘uplift’ to estimates of current velocity to account for the effect of tidal and inertial currents in cases when observations or model estimates do not resolve the high-frequency current variability. The value of the ‘uplift’ is assumed to be proportional to the intensity of the low-frequency flow. Our analysis aims at testing whether this assumption is valid by providing a detailed description of the space-time variability, including seasonal changes, of inertial oscillations in the central northern Gulf of Mexico. From the analysis of long-term current profile observations and drifter data we found that, on average, near-inertial oscillations have higher amplitudes outside of the areas of strong low-frequency currents associated with a Loop Current Eddy (LCE). Within the upper 200m of the water column, periods characterized by the downward energy propagation dominate. In the layer below 200m, near-inertial waves propagate upward and downward, and the wave trains cannot be traced to a single source of energy. This suggests near-inertial waves within the main part of the water column are of ‘global’ rather than of ‘local’ origin. For most near-inertial wave generation events through wind forcing, the downward energy propagation could not be traced for any extended period of time and no deeper than approximately 200-m depth. The rate of downward energy propagation in the upper pycnocline is on the order of 10-12 m/day. For the near-inertial currents, the first two Empirical Orthogonal Functions (EOF) contribute only 40% into the total current variability for the period of LCE presence and 52% for the period of benign current conditions. The mode shapes vary within a wide range that, most likely, reflects a random distribution of mode shapes that depend on the lateral geometry of the forcing, mixed layer depth, and stratification.
Development of a Passive Magnetic Radial Bearing System for Electric Submersible Pumps ESPs
Authors: McMullen Patrick , Biddick David , Artinian Herman 
Published: August 2021

Abstract
This development is the result of a DeepStar program to build and test a new radial passive magnetic bearing system (PMB) for downhole tools. While slated for the Magnetic Drive System (MDS) ESP, an advanced high-speed ESP that uses magnetic fields to increase performance, reliability and retrievability, this technology is applicable to conventional ESPs. The PMB supports the motor rotor across large clearances with no physical contact via magnetic fields in the ESP.
An MDS ESP preliminary design was developed, from which the size and integration requirements of the PMB were defined. These requirements guided the analysis, design and testing of the full-scale components. Empirical analysis tools were used for initial iterations in size and performance of the PMB, followed by detailed magnetic finite element analysis (FEA) using commercial validated tools for the final performance prediction. With analytical validation of performance, detail designs were developed and hardware fabricated. Hardware testing was done to validate performance predictions and alignment with system requirements.
The feasibility, preliminary design and analysis of the PMB were conducted in Phase 1 of the DeepStar Program and has continued with the full-scale design, build and test results of Phase 2. PMB performance results include load capability and deflection during static load events, all in relation to validating performance for use in the MDS system. This test data is used to validate the analysis approach used as well as to finalize the integration size of the PMB to meet the performance requirements of the MDS system. With the PMB large (&gt;14mm) clearance between rotor and stator magnets, testing also includes variations in axial and radial position of the rotor in relation to the stator to account for installation variations in the MDS as well as use of sealing materials on both the rotor and stator. Integration is planned for use of the PMB in the MDS, so integration testing is planned to validate performance for each of these areas.
This technology offers a radial bearing that can greatly enhance ESP performance and reliability. The PMB is a contact-less bearing system that does not require lubrication, can operate with large clearances to allow free fluid flow, is easily fully sealed from the environment, has virtually no bearing rotating losses, and has no operating life limits.
Development of Failure Prediction Models for Subsea Blowout Preventers Using Data Analytics and AI
Authors: Machado Rodrigo Chamusca , Leite Fabbio , Xavier Cristiano , Albuquerque Alberto , Lima Samuel , Carvalho Gustavo 
Published: August 2021

Objectives/Scope
This paper presents how a brazilian Drilling Contractor and a startup built a partnership to optimize the maintenance window of subsea blowout preventers (BOPs) using condition-based maintenance (CBM). It showcases examples of insights about the operational conditions of its components, which were obtained by applying machine learning techniques in real time and historic, structured or unstructured, data.

Methods, Procedures, Process
From unstructured and structured historical data, which are generated daily from BOP operations, a knowledge bank was built and used to develop normal functioning models. This has been possible even without real-time data, as it has been tested with large sets of operational data collected from event log text files. Software retrieves the data from Event Loggers and creates structured database, comprising analog variables, warnings, alarms and system information. Using machine learning algorithms, the historical data is then used to develop normal behavior modeling for the target components. Thereby, it is possible to use the event logger or real time data to identify abnormal operation moments and detect failure patterns. Critical situations are immediately transmitted to the RTOC (Real-time Operations Center) and management team, while less critical alerts are recorded in the system for further investigation.

Results, Observations, Conclusions
During the implementation period, Drilling Contractor was able to identify a BOP failure using the detection algorithms and used 100% of the information generated by the system and reports to efficiently plan for equipment maintenance. The system has also been intensively used for incident investigation, helping to identify root causes through data analytics and retro-feeding the machine learning algorithms for future automated failure predictions. This development is expected to significantly reduce the risk of BOP retrieval during the operation for corrective maintenance, increased staff efficiency in maintenance activities, reducing the risk of downtime and improving the scope of maintenance during operational windows, and finally reduction in the cost of spare parts replacementduring maintenance without impact on operational safety.

Novel/Additive Information
For the near future, the plan is to integrate the system with the Computerized Maintenance Management System (CMMS), checking for historical maintenance, overdue maintenance, certifications, at the same place and time that we are getting real-time operational data and insights. Using real-time data as input, we expect to expand the failure prediction application for other BOP parts (such as regulators, shuttle valves, SPMs (Submounted Plate valves), etc) and increase the applicability for other critical equipment on the rig.
Mooring Integrity Management through Digital Twin and Standardized Inspection Data
Authors: Matsumoto Shunsaku , Jaiswal Vivek , Sugimura Tadashi , Honjo Shintaro , Szalewski Piotr 
Published: August 2021

Abstract
This paper presents a concept of a mooring digital twin frameworkand a standardized inspection datatemplate to enable digital twin. The mooring digital twin framework supports real-time and/or on-demand decision making in mooring integrity management, which minimizes the failure risk while reducing operation and maintenance cost by efficient inspection, monitoring, repair, and strengthening. An industry survey conducted through the DeepStar project 18403 identified a standard template for recording inspection data as a high priority item to enable application of the digital twins for integrity management. Further, mooring chain was selected as a critical mooring component for which a standard inspection template was needed. The characteristics of damage/performance prediction with the proposed mooring digital twin framework are (i) to utilize surrogates and/or reduced-order models trained by high-fidelity physics simulation models, (ii) to combine all available lifecycle data about the mooring system, (iii) to evaluate current and future asset conditions in a systematic way based on the concept of uncertainty quantification (UQ). The general and mooring-specific digital twin development workflows are described with the identified essential data, physics models, and several UQ methodologies such as surrogate modeling, local and global sensitivity analyses, Bayesian prediction etc. Also, the proposed digital twin system architecture is summarized to illustrate the dataflow in digital twin development andutilization. The prototype of mooring digital twin dashboard, web-based risk visualization and advisory system, is developed to demonstrate the capability to visualize the system health diagnosis and prognosis and suggest possible measures/solutions for the high-risk components as a digital twin's insight.
18 3/4" 15000 Psi Shear Anything KBOS for Subsea Well Applications
Authors: Gallagher Bobby J , Dupal Ken , Jones Reese E 
Published: August 2021

Abstract
Kinetic Pressure Control has developed the 18 ¾" 15000 psi blowout stopper (KBOS) system for applications on all subsea well activities. The 18 ¾" 15000 psi systems builds upon the successful development of the 5-1/8" 15000 psi KBOS system for surface BOP applications[5]. The system can be configured within the existing subsea BOP, by replacing a casing shear ram or blind shear ram, or can be configured as a shut-in device below the BOP. The KBOS system provides a significant improvement over existing shear ram technology, providing the ability to shear/seal any items in the wellbore, which reduces the likelihood of a blowout, resulting in an improved risk profile.
The KBOS is a proprietary design which uses a pyro-technical, electrically initiated process the actuate the shearing process. The system has been designed and tested to actuate and shear/seal in milliseconds, under full wellbore flowing conditions and meets NACE/ISO sour service requirements without exemptions. The control system includes real-time monitoring and function testing capabilities, and requires minimal in-service maintenance, as the working components are isolated from the wellbore fluids. A computational predictive model has been developed, with a test regime conducted to validate the model results. A full qualification program, with 3rd party certification, has been completed to industry standards.
Shearing tests have been conducted for a large range of tubulars which have been challenging to shear with existing technology. These include: 9 ½" drill collars, combinations of large OD casing and inner strings, high strength drill pipe and tool joints, wireline, and production tubing. A subsea test of the system was successfully performed in 2019 to shear large OD casing and inner string.
The KBOS system utilizes technology from other industries (ballistics, military, automotive) to provide improved shearing and sealing capabilities for all well activities (drilling, completion, intervention). The improved shearing/sealing capacity and reduced time enable a reduced likelihood of a blowout and improved risk profile
Buzios FPSO Experience: Standardization and Perspectives for Our Next Generation of Pre-Salt FPSOs
Authors: Padua Mattoso Marcio de , Goulart Pimenta Maiza 
Published: August 2021

Abstract
The purpose of this article is to present a set of experiences and challenges related to the current Buzios FPSOs and the perspectives offered by these related experiences, which should drive further enhancements for next generations of pre-salt production units.
Buzios field is a giant oil discovery located at Brazilian southeast coast and has four production systems already in operation: P-74, P-75, P-76 and P-77. Throughout these projects, Petrobras observed technical and business opportunities that are going to lead improvements for next generation of Buzios field's FPSOs. These include enhancements on high production wells, H2S removal technology, vessel standardization, digital transformation solutions, design procedures improvements and several measures to strength the integration between design, construction, commissioning and operation phases.
During the construction, commissioning and startup period of the Buzios’ current installed units, Petrobras identified technical issues that should be addressed in order to add value to the next generation of Buzios’ FPSOs. These experiences point out to the need of technical design improvements and reviews such as: change in technology of H2S removal from solid bed to membranes; a complete analysis of hull capacities and dimensions and standardization of the vessel; and a set of standardization methods and processes to develop the basic design - including aspects of digital transformation. The result was a standard design project called Reference Project ("Projeto de Referência" in Portuguese) that intends to be a reference for new units to be installed in Buzios field. This design also intends to be the basis to other projects in order to allow faster business decisions.
Monitoring and Calibration of Long Term Mooring System Design Assumptions Through Use of AIS and Weather Data
Authors: Lillestøl Dag Børre , Kårvand Odd Torbjørn , Torstensen Are 
Published: August 2021

Abstract
This paper outlines an approach on how to improve the mooring integrity of existing long term mooring systems by using existing and commercially available data.
It will be demonstrated how the use of AIS and hindcast weather data can be used to increase understanding of mooring systems and to monitor and quantify gaps between "as-designed", "as-installed" and "as-is" of a long term mooring system.
Long term moored units have traditionally suffered from many early failures, caused by damages and errors introduced in the installation phase, and costly and unnecessary "late in life" failures. A fact rated high on the agenda of the underwriters. Numerous papers have been written on this topic, but it is only in recent years the industry have started to ensure that systems are inspected to a sufficient degree with respect to the physical condition, taking these learnings into account. However, the second important element, the calibration of the mooring analysis vs. actual vessel and mooring system behavior/performance, have not yet gotten the attention required.
Deviations from the intended design are introduced in the installation phase of a mooring system. In addition, the design assumptions will never be fully accurate. The gap between the design assumptions and the actual system will increase over time, and the industry today do not focus on mapping and quantifying the effect of this gap sufficiently. The described method explains how one can introduce a pro-active approach, without installing onboard equipment, but rather utilizing algorithms on existing data and design documentation.
This paper focuses on the use of AIS data in combination with historic weather/environmental data and seek to demonstrate how this low-cost method can provide useful information with respect to the mooring system.
To emphasize the mapped importance of such calibrations, the July 2021 Edition of the in-service DNV Class Rules, DNVGL-OS-0300, formally introduces requirements to calibration of design assumptions of long term mooring units through use of survey data, service history and actual mooring system behavior in order to ensure a unit's mooring system condition and performance is known in light of the original design assumptions.
Impact of Rheology Models on Horizontal Well Polymer Flooding in a Heavy Oil Reservoir on Alaska North Slope: A Simulation Study
Authors: Leng Jianqiao , Wei Mingzhen , Bai Baojun , Seright Randall S. , Zhang Yin , Cercone David , Ning Samson 
Published: August 2021

Abstract
Polymer rheology can have either a positive or a negative effect on polymer flooding performance under varied circumstances. Many researchers have studied the effect of polymer rheology in a vertical well, but no field scale studies have been conducted to investigate whether polymer rheology is beneficial to polymer flooding in heavy oil reservoirs developed by horizontal wells. In this paper, we conducted a numerical simulation study to examine the effect of HPAM polymer rheology on a polymer flooding pilot, which is the first-ever project conducted on a heavy oil reservoir from Alaska North Slope (ANS) developed by horizontal wells. Three rheology types were considered in the study including the apparent viscosity measured during coreflooding of using a HPAM polymer, the bulk viscosity measured with a viscometer, and a Newtonian flow model. The results suggest that using the bulk viscosity in simulation underestimates the conformance control and the water-oil-ratio reduction capability of the HPAM polymer solution. When the apparent viscosity is used, the incremental oil and sweep were largely increased, and the optimal recovery period of polymer flooding was extended greatly, especially for the heterogeneous formations. Therefore, the rheology type of polymer plays a significant role in the incremental oil recovery and injection profile of the horizontal well system given the pilot testconditions. This study has provided practical guidance to field operators for the ongoing polymer flooding pilot on ANS and will also provide valuable information for other polymer projects conducted in similar conditions.
Repurposing Oil & Gas Wells and Drilling Operations for Geothermal Energy Production
Authors: Pilko Robert M. , Hart-Wagoner Nicole Rita , Horn Andrew J. Van , Scherer Joseph A. 
Published: August 2021

AbstractThis paper explores a market solution for Operators’ companies to compound their investments in wells, fields, and infrastructure in a low carbon world by applying improved well design, drilling and completion technologies that are adapted to a new generation of geothermal energy production systems. The paper frames challenges posed to the upstream industry by the movement to a low carbon economy, including the climate transition risks related to societal, regulatory, and capital allocation trends. It then examines the technical challenges and solutions related to repurposing oil and gas fields and wells for geothermal energy production and makes high-level recommendations for Operators interested in accessing this new market for geothermal energy - as well as satisfying Environmental, Social and Corporate Governance (ESG) investors.