bluuebunny/crossref_metadata_2025_split huggingface dataset:
Downhole Data Analysis for Pressure-Pulse-Generating Tool Coupled with a Shock Tool
Authors: Trinh Khoi , Khan Alamzeb , Riddel Jake , Forster Ian , Forrester Stephen 
Published: April 2019

High levels of friction, especially in horizontal and extended-reach operations, can be a major concern during sliding or rotating. Friction increases drag, which increases the required torque and weight on bit (WOB), thereby reducing efficiency. Other related issues include excessive tool wear, lower rate of penetration (ROP), and poor directional control. There are several methods used by the industry to combat the torque and drag phenomenon, one of which is the use of a drilling agitator tool (DAT). A DAT is commonly used in extended lateral formations to improve weight transfer to the bit. The operational principal of the DAT is the production of a pressure pulse that causes a repetitive axial motion. A DAT consists of a pulse generator and displacement generator, also known as a shock tool (ST). The system ultimately produces axial oscillation in the drillstring, which helps reduce the effective frictional coefficient regardless of whether the string is sliding or rotating. The DATs are sometimes used in conjunction with standalone STs, which are placed in a remote location where the DAT displacements may be out of range. Standalone STs placed at the bottomhole assembly (BHA) also help isolate downhole dynamics, improving drilling efficiency.
The objective of this study is to see how a DAT and ST combination impacts drilling. Furthermore, a closer look is taken at the impact on the operational drilling efficiency of drillstrings with a DAT and standalone ST. These results are discussed in detail and supported by high-resolution data collected during drilling.
The information presented in this paper can be used to evaluate the performance of DAT and ST combinations, their impact on drilling performance, and their zone of effectiveness. The data analysis presented here also provides an in-depth look into the operation of a DAT and how the BHA below the DAT is impacted by its operation. This study takes data from a novel, small, self-contained tool located directly above and the DAT, ST, and the BHA. This tool measures axial vibration, internal pressure, temperature, and axial displacement, allowing a comparative assessment to be made and delivering information about drilling performance that is otherwise not available via conventional downhole measurement tools. This new measuring tool specializes in collecting high-speed data in memory mode and is dedicated to the analysis of the operation of the DATs.
Application of an Enhanced Lazy Wave Flexible Riser System in Extreme Shallow Water with an External Turret Moored FPSO
Authors: Hou Yucheng , Yuan Jiabei , Tan Zhimin , Witz Joel 
Published: April 2019

This paper presents the design challenges encountered in a flexible riser application with an external turret moored FSO in a shallow water depth around 55m, and the solutions obtained for an improved lazy wave flexible riser system. Extensive dynamic analyses were performed with parametric variations and a model test was also carried out to validate the predicted dynamic responses.
The lazy wave flexible riser system is preferred for shallow water applications due to it being cost effective in terms of both fabrication and installation, and high reliability in operational performance. The system relies on the balance of the riser system weight and buoyancy applied, and it is required to accommodate large excursions and dynamic motions of the mono-hull vessel induced by the environmental loadings. The riser system weight varies due to pipe contents changes and heavy marine growth. When the water becomes shallower, the challenges escalate to maintain the riser system to remaining in suspension without clashing with the sea bed or vessel. An enhanced Lazy Wave Flexible Riser solution, a patented technology of BHGE, was adopted. In this technology, the ballast modules were used innovatively to maintain the configuration in suspension by automatically compensating the riser weight variation during entire service period.
The paper also summarizes preliminary benefits of the improved lazy wave flexible riser technology over the potential alternative technologies for such shallow water application, for example, the traditional S configuration and the latest middle-water-jacket configuration. Both alternatives involve significant high cost in fabrication and installation.
Optimization of Well Start-Up Using Integrated Well and Electrical Submersible Pump Modeling
Authors: Mukati Kapil , Wilson Oliver , Morales Milton , Arias Brian , Terry Clinton 
Published: April 2019

Abstract
An integrated multiphase flow well and electrical submersible pump model was used to optimize operating procedures for initial well clean-up and ramp up to production for a major deepwater production system before first oil. An integrated modeling approach was crucial to create and test start-up scenarios given uncertainty in the amount of completion fluid in tubing, uncertainty in density of near wellbore fluid and lack of prior experience in ESP operation.
The model was used to simulate numerous well start-up scenarios:Well BS&W rate profiles as a function of frac pack fluid recovery percentageWell unloading profiles as a function of injected base volumeNatural flowing well start-up profilesChemical injection volumes and associated surface injection pressuresPressure surging across the completion during ESP start-upsNumber of "A" annulus bleeds required during initial start-up
Accurately simulating such highly transient scenarios requires integrating multiphase flow phenomena in tubing to reservoir inflow and dynamic pump behavior. The integrated model proved to be very valuable in finalizing well start-up procedure with a high degree of confidence. This fully dynamic model can estimate phase, pressure, temperature and flow anywhere in the tubing including effect of well choke operations, pump pressure and temperature dynamics based on speed, effect of downhole conditions, and reservoir inflow. The transient behavior in tubing and annulus upon switching on or off ESP pump during well operation is also accurately represented.
In this paper, we will present how the integrated model was developed, how it was used to simulate various scenarios and how the results were used to create and validate well start-up procedure. The methodology presented here is applicable to any well using ESP artificial lift methods. This model is a very useful tool not only for engineering simulation, but for operator training and real-time surveillance as well.
A New All Electric Subsea Control System Development
Authors: Monteverde Carlo , Novello Marco , Kristiansen Karstein 
Published: April 2019

AbstractOver the past few years a specific programme has focused on the development of subsea separators and a subsea water treatment and injection process composed of several modules and requiring a certain amount of new subsea technology (subsea barrier fluid-less water injection pumps, filters, special water analyzers, etc.). One of these technologies is the all-electric subsea control system.The all-electric versus the electro-hydraulic solution was selected for its inherent capability to:enable long step-out distances;run logics such as sequences and fast closed control loops involving subsea proportional valves;handle high frequency of simultaneous valve actuations;implement safety functions, including SIL certified, when required.Within the ongoing industrialization programme of the new technologies, a Joint Development Agreement has been put in place between two partners for the qualification of the open framework platform for the control of subsea processes.The development is pursued according to the API 17N and DNV RP-A203 requirements.The subsea control system is developed according to the approach to interface standardization, which is aimed at guaranteeing:–the interchangeability of modules coming from different vendors;–the reduction of physical interfaces;–the optimization of IMR intervention time.The technology mainly consists of:a qualified basic component platform to be used for project-based assembly;a complete set of tools such as web-server, condition monitoring server, integrated software development environment, etc.;a standard and user-friendly approach for software application development, based on P&ID graphic, in order to facilitate the sharing of software information between contractor and clients;standard industrial communication protocols (no proprietary protocols) accessible to all users, which are designed for easy interfacing of the control system with third party equipment.The JDA activity has concluded the Q1 qualification tests of electronic components and Q2 tests of electronic assemblies, pursuant to API 17F, as well as all the other qualification activities (tests and analyses) relevant to the non-electronic components (e.g. 40kVA subsea electrical transformer), according to the relevant technology qualification plan. Additional software packages have also been developed and successfully tested using the Test Driven Development (TDD) method.The qualification will be completed by Q1 2019 with integration tests of:–Topside Control System;–Subsea Power and Communication Distribution Manager;–Subsea Control Unit.The integration tests will allow to reach TRL 4 of the above subsea equipment, in accordance with API 17N.
A 3D Digital Approach to Flow Assurance
Authors: Bouamra Reda , Petit Pierre , Smuk Stefan , Vielliard Christophe 
Published: April 2019

The oil and gas industry has long perceived computational fluid dynamics (CFD) as a computationally expensive, high-end simulation method to analyzing extremely complex behavior. However, the recent increase in computational power and the democratization of CFD packages have enabled 3D modeling to become part of the regular in-house execution scope. This paper presents a range of flow assurance CFD applications and shows the impact of 3D workflows in the overall system design, the adoption of standard specifications, and fast-track project executions.
As oil and gas fluid journeys from the reservoir pore space to production facilities, it faces a wide range of complex flow assurance issues related to the nature of the live production fluids (compositional changes, viscosity, compressibility), the production system environment (high and low pressures) and its interaction with hardware (erosion, flow induced vibration, scaling). One-dimensional mechanistic models are used to solve these flow hindrance issues in wells and pipelines but provide limited results in the complex geometries of subsea and subsurface equipment.
In subsurface applications, a CFD workflow was used to tune near-wellbore reservoir properties based on advanced 1D and 3D thermal modeling of the completion interval. Accurate thermal modeling was then used to manage downhole flow assurance issues (e.g., asphaltenes and scale buildup). In subsea equipment, the methodology was used to fast-track project execution by using standardized equipment using project specific parameters at an early stage. CFD analyses were used to estimate the risk of erosion and flow-induced vibration in a subsea tree. The thermal aspect was not neglected because CFD conjugated heat transfer was used to detect cold spots and improve the thermal behavior of insulated equipment (trees, manifold) during normal production and shutdown. To avoid long and expensive material qualification campaigns, CFD was used to define the temperature gradient in trees and compare the design temperatures of materials against their calculated temperatures.
The ability to perform advanced CFD calculations has become a true enabler in the ability to adopt standardized equipment and supplier-led specifications on subsea field development applications, thus contributing to better capital efficiency and shorter time from discovery to production. Several concrete examples from wide-ranging subsea field development projects worldwide are presented to illustrate the added value of CFD in all stages of engineering, from concept definition to project execution.
Industrialisation of SPRINGS®, A Qualified Subsea Sea Water Desulfation Process
Authors: Giolo Riccardo , Berthelot Aurelie , Pedenaud Pierre , Skivington Graeme 
Published: April 2019

SPRINGS® (Subsea PRocessing and INjection Gear for Seawater) is a qualified process for subsea water treatment and injection. It uses membrane technology for water desulfation upstream of water injection wells to prevent sulfate scaling on the production side (nearwell bore, well and production equipment). It moves the water treatment from topside to subsea locations close to the injection wells with only power and communication tie-backs to existing topside facilities. Qualification of the process was achieved through both onshore and offshore trials.
In advance of deploying the first industrial application, an industrialisation programme was undertaken in order to ensure that every component necessary for the subsea process implementation was available and had a sufficient technology readiness level to be safely installed and operated within the subsea plant.
The existing and available technologies were reviewed vis-À-vis the requirements arising from both the process and the business strategy. Several industrial partners were engaged to determine the elements of novelty that needed to be brought to each technology or component to satisfy such requirements.
The new technologies included:
Subsea barrier-fluidless pumps
Open framework all-electric control systems
High-cycling electric actuators and valves
Subsea water analyser
Subsea storage and injection units for chemicals
The design basis for the development of each technology, which in most cases included the realisation of a prototype and relevant qualification testing, was set up to consider a range of possible applications with differing environmental conditions, process data and/or IMR scenarios. The most challenging conditions were selected for each development to determine the relevant required performance.
Where available, specific standards, such as API 17F (ref. [8]) for subsea electronics, were followed to determine the qualification plans. In those cases where no dedicated specific standard was available, the evaluation of the proposed solution was performed in conjunction with the technology provider through the risk based approach stated in API 17N (ref. [9]) and DNV A203 (ref. [10]). Failure Modes, Effects and Criticality Analyses (FMECAs) as well as technology readiness assessments were performed in order to develop the technology qualification plans.
Most of the key equipment qualification plans will be completed by mid-2019, establishing an industrial platform for the deployment of the subsea water treatment and injection technology in a completely all-electric configuration, i.e. connected to the surface only through a communication and power cable. Such an industrial platform will also contain the building blocks for other subsea processes.
The presentation and paper will introduce the elements of technological novelty and will describe the process, the challenges and the results of the relevant qualifications.
New Concepts for a Normally Unattended Installation NUI – Design, Operation, Automation, and Digitalization
Authors: LaGrange Elgonda , Maisey Joel 
Published: April 2019

Abstract
This paper is based on an ongoing multi-participant study which focuses on the development of concepts for unmanned or "Normally Unattended Installations" (NUIs) that can be used for the economic recovery of stranded oil and gas reserves considered too small for traditional floating production storage and offloading (FPSO) vessels, and too far away from existing facilities for tie-backs.
The primary objective of the study is to apply existing technologies in novel ways and to utilize recent advances in digitalization to develop low manning concepts by facilitating remote control, remote monitoring, and reducing maintenance requirements. The study engaged key technology vendors and operators, who provided operational expertise and defined future operation philosophies. Concepts are being validated by classification societies, yards and installation contractors.
The specific NUI concept explored in this paper is an unmanned production buoy that proved to be technically and economically feasible for the recovery of small hydrocarbon pools in deeper water. The case study is a realistic approximation of a small deepwater offshore development in the North Sea, however, it is not based on any specific prospect. The case study Basis of Design (BoD) has been defined to cover a range of API gravities, ensuring that the resultant topsides design concept is robust and applicable to a range of real field developments in the future without significant re-configuration.
The study into the technical and economic feasibility of the unmanned production buoy considered alternatives for gas compression, treatment, separation; heating and cooling, power generation, automation systems, and digitalization. This paper presents the outcomes with respect to production buoy design, operating philosophy, automation and digitalization.
Standardization of Procurement Equipment Specifications: A Step Change in Facility Cost and Schedule Reduction
Authors: Postema Adri , Wish David 
Published: April 2019

Abstract
Over the past decade, projects across the oil and gas industry have been plagued by cost and schedule overruns, exacerbating underlying cost escalation. Rising project costs must be addressed to ensure long term viability of the future capital programs. Standardization is widely recognized as part of the solution, and individual companies have been progressing standardization of specifications within their own businesses. However, the standardization journey is only just beginning: the oil and gas industry still lags others such as the automotive and aviation, as individual companies each maintain their own amendments on otherwise established industry or international standards.
Joint Industry Program 33 (JIP33), now in its third phase, aims to unlock significant value and drive a permanent reduction in project costs through the development and use of industry-level, global technical specifications for procurement of bulk materials, packages, modules and potentially, even projects.
Intelligent Completion in Extended Well Test
Authors: Coccoli Flavio Costa , Cruz Luiz Carlos Milagre , Vasconcelos Thiago Henrique Galindo , Marti Rogério Pinto 
Published: April 2019

Abstract
This paper describes the wells completion design, operational performance and use of intelligent completion by Libra Consortium for EWT wells. Additionally, it will describe new technologies that will support the full field development.
The paper presents the de-risking plan EWT Program implementation to help full field development, which consists up to four ultra-deepwater mega projects. The EWT wells were assumed as keepers, thus designed as convertible, with metallurgy requirements for both oil production and Water Alternating Gas injection. The intelligent completion, with multi-position valves for each production zone, was selected to allow choking-back gas coning, early gas breakthrough or water production in one zone, while another remains opened. These valves were useful to determine vertical communication between different reservoir zones, making it possible to have buildup in one zone while producing another.
Four appraisal wells were completed, for the EWT program up to now, using a full-dual rig. Three of the completions were in sequence, providing a sound learning curve with a significant time reduction, and no installation problems. It was noticeable a correlation between improvement in operational efficiency and a decrease in HSE incidents. The use of intelligent completion made possible an efficient well stimulation, avoiding inter-zonal communication during the acid job. A production rate higher than 60 kboe/day was reached and 100 MM scf/day gas was re-injected. This injection rate implied risk of control lines fatigue due to induced vibration, therefore a Computational Fluid Dynamics (CFD) study was required to determine the maximum injection rate. The Operator implemented mitigation measures for intelligent completion valves actuation since some operational difficulties were observed during the EWT. These situations did not affect the EWT information acquisition plan, but represented significant operational experience for Mero Field future development projects, where multiplexed intelligent completions and open-hole intelligent completion are being also considered.
The approach taken by Libra Consortium helps to gain early experience about well design for carbonate reservoirs and intelligent completion behavior, with high CO2 and GOR, where gas re-injection is a necessity and the use of intelligent completion is a mandatory strategy. The performance of the completion design fitted the field evaluation purpose and the wells will be successfully used as keepers.
Metocean Decision Making Lessons-Learned during an Oil & Gas Construction Project Conducted in a Harsh Coastal Environment
Authors: Bullock Terry William , Beale Steven Thomas , McCarthy Ron , Kelly Hugh Anthony 
Published: April 2019

Abstract
The Hebron Platform was constructed from 2012 to 2017 in the harsh environment of coastal Newfoundland and Labrador. The construction site experienced winds and seas that approached expected values for a 100-year return period event, unusual non-tidal water levels during topsides / GBS mating, and historically extreme sea ice conditions that delayed tow-to-field operations. Topsides marine operations required data collection and forecasting system enhancements more than 2 years in advance due to the sensitivity of the operations, and the complex topography and climate of the site. Installation offshore was limited by winds, seas and long period swells that could reach the site from remote areas of the Atlantic. A summary of metocean support for the Hebron Platform is presented with lessons learned and comparisons made with the Hibernia Construction Project executed 20 years earlier in the same location.
Several technologies were applied to the Hebron Project that were not available during the Hibernia Project. Emerging technologies combined with in-situ measurements of atmospheric and oceanic conditions were used to provide operational metocean support for the Hebron Project. Examples of effective processes are described that could apply to similar harsh environments, complex terrains or northern coastal construction projects. There were also technologies attempted which were deemed unfeasible. Complex metocean decision making for an environmentally sensitive oil and gas construction project is described within a quantitative risk assessment framework.
Embedded experienced metocean personnel used advanced information behind the scenes to improve forecast accuracy and to provide guidance on the timing and likelihood of threshold-exceedance events. It was demonstrated that an effective metocean decision making process was highly dependent on forecast magnitude and timing accuracy at various forecast horizons. It was found that specific operational parameters and governing, operational weather windows for the Hebron Project were achieved with minimal waiting on weather due to a ‘go/no-go’ decision making process which was based on confidence in the forecast accuracy, and a risk assessment system that embedded metocean specialists with the relevant event-likelihood information. Operational delays due to unreliable forecasting would have led to significant delays, personnel and equipment downtime, and cost over-runs for the Hebron Project.
Weather forecasting in support of the Hebron Project demonstrated that metocean analytic and predictive science has improved sufficiently over the past 20 years to effectively support oil and gas exploration and development operations that have moved into harsher environments.