bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sortie nature, protocole et hybridité cognitive. Note sur les sciences participatives
Authors: Charvolin Florian 
Published: March 2018

L’expérience de plein air, hors du confinement des disciplines académiques, engage une hybridité cognitive particulièrement nette dans le cas de dispositifs associant scientifiques et amateurs. La multiplication actuelle des sciences participatives réclame de se pencher sur ces lieux du « grand air », qui renversent la préséance du laboratoire, pour faire de la sortie nature et du protocole observé en plein air leur centre de gravité. L’article prend la mesure du phénomène des sciences participatives et propose une lecture de ses performances pour l’acquisition de connaissance et le type de sociabilité et d’accomplissement qui s’y joue.
Qualification of Low Cost Buoyancy LCB for Deepwater Towed Bundle Applications
Authors: Loentgen Vincent , Pezet Peter , Goodlad Martin , Eyssautier Stephan , Brayshaw Simon , Brouard Yann 
Published: March 2018

Abstract
Since Deepwater field developments started around year 2000, Deepwater Buoyancy has been dominated by syntactic foam and has not evolved significantly since then. Some Deepwater applications like towed Bundle, Steel Lazy Wave riser and Hybrid Riser towers require large amounts of it, both for temporary (installation aids) use and permanent use, becoming a significant part of the cost associated to those systems. In parallel, the present market conditions is pushing Oil companies to develop new technologies and to promote cost reduction initiatives.
In this context, Subsea7 and Matrix, Composites & Engineering have developed a new concept of buoyancy, so called low cost buoyancy. This paper will present the Buoyancy concept, will provide insight on the qualification tests successfully passed, and present typical application where the low cost buoyancy is intended to be used.
Verification of Barriers in a Suspension or Abandonment Phase
Authors: Stein Arild 
Published: March 2018

Abstract
Installing and testing a new deep wellbore barrier in older assets has proven to be challenging, especially when previously installed devices are difficult to remove from the well. When a new barrier is installed in close proximity to the old device it makes it extremely hard to assure integrity of the upper barrier due to the small volume that exists between the two. Only by measuring the pressure between the devices can the integrity of the newer barrier be correctly verified. Isolating a reservoir by installing a deep barrier, complete with Barrier Verification System (BVS) logging the pressure across the barrier, will give much quicker assurance that the barrier has in fact isolated the reservoir.
The BVS consists of a pressure sensor with a wireless transmitter attached below the barrier. The receiver is included in the setting tool above the barrier to be tested and wirelessly records the pressure from below the installed barrier. An additional pressure sensor in the receiver forms part of the tool to provide an accurate pressure over the established barrier. The receiver can transfer real time data on e-line to surface, or be deployed in memory mode for slickline or other intervention methods.
As part of the barrier verification the setting log from the Electronic Setting Tool (EST) is recorded. This data is part of the integrity verification package to the customer. Data can be verified against our extensive database of previous logs taken from products across our range. In wells where tubing condition is not mapped, the EST log can confirm if the load profile of the barrier is correct and has been set within its setting range.
The paper will look at the operational use and verification obtained with the technology, the savings and enhanced reliability with documented installation profiles in execution of a multi-well suspension operations in the North Sea, and the behavior and stability of the well before and after the intervention operations.
Capex and Opex Benefits of Wireless Instrumentation in Not-Normally Manned Wellheads
Authors: Mahadevan Raja Karthikeyan 
Published: March 2018

Abstract
It is well known that the oil and gas industry is going through a difficult phase and in the current down trend, cost optimization is the prime focus for all oil and gas operators. At the start of a new project, the conceptualization and cost benefits in Instrumentation are considered as key parameters and also the implementation pf these should be utilizing the latest technologies. "Wireless Instrumentation" is considered as one of the prime focus area for new projects that are under conceptualization and when at the planning stage.
This technical paper explores the benefits of implementing the state of the art technology "Wireless Instrumentation" by comparing the Capital Expenditure (CAPEX) and Operational Expenditure (OPEX) in "Not Normally Manned Well Head Platforms". Although this paper concentrates on the benefits with respect to the not normally manned well heads platforms only, however the topics taken for discussion can be extended to cover Processing Facilities, FPSO's and also other onshore facilities.
Decoding Interwell Tracer Data Using Novel Analytical Approach to Optimise Waterflood Management in a Complex Oil Rim Field, in Offshore East Malaysia
Authors: Tiong-Hui Wong , Cheng Sean Toh Zit 
Published: March 2018

Abstract
As waterflooding has become one of the most favorable approach for secondary recovery globally, understanding flood front behavior and reservoir sweep becomes even more pertinent to maximize recovery. To monitor the effectiveness of a waterflood program, chemical tracers are often deployed for enhancing surveillance techniques. This paper presents a classic example of value creation from the existing tracer database with the demonstrated workflow of the Residence Time Distribution (RTD) method in tracer interpretation applied in a mature waterflood field. The analytical study conducted was in a complex oil rim field located in East Malaysia.
As a five-year sampling programme was initiated for this field, a substantial amount of sample and corresponding tracer response data allowed the field to be a strong candidate for tracer RTD data analysis. Injection was carried out via smart wells into 28 zones and samples were taken on routine basis from monitored producers. Breakthrough of unique tracers coupled with low detection levels from the vendor laboratory were utilized as a foundation for constant waterflood optimization. Flow geometries and reservoir continuity between each injector-producer pairing were measured in detail through analysis of chemical tracer response curves.
Apart from immediate injector-producer communication upon first tracer breakthrough, a detailed study on water flood performance based on the RTD method allowed the pore volume swept, mass recovered from each section and quantification of heterogeneity to be determined. Flow geometry and reservoir continuity between each injector-producer pairing were also measured allowing identification of thief zones, out of zone injections, vertical communication between layers, and behind casing flow. As a result, the information gathered allowed the optimization of each injection zone based on the outcome of the tracer response at the respective producers. This information has proven beneficial to the reservoir surveillance team allowing insightful decisions to be made upon subsequent opportunities for production and water flood optimization.
Cost Effective Riser Solutions for Deepwater Gas Developments: Steel Lazy Wave Riser and Tethered Catenary Riser
Authors: Eyssautier Stéphan , Ryan John , Brouard Yann , Erwin Roniawan Kemas , Germanetto Florian 
Published: March 2018

Abstract
Deepwater gas fields require large diameter risers to provide high flowrate. Flexible Risers are limited to about 18", whereas Steel Catenary Risers (SCRs) can go beyond that, for example 20" or 24"OD. Because those SCRs are sensitive to fatigue, they are equipped with Buoyancy Modules (BM) to decouple them from surface dynamics: they form a Lazy Wave configuration and they are therefore called Steel Lazy Wave Risers (SLWR). To solve more stringent fatigue issue, decoupled riser system like SHRs are very efficient.
The objective of this article is to present innovative alternatives to conventional development.
This paper will present a novel decoupled riser system: the Tethered Catenary Riser (TCR) previously presented at the Offshore Technology Conference (Legras 2013; Legras & Neel 2014). The installation aspects have been further developed and are now only based on field proven and reliable installation procedures. The TCR can be considered as a robust solution for gas development projects, being the most cost efficient decoupled riser system.
This paper will also present an alternative solution to install traditional Steel Lazy Wave Riser (SLWR) using a towing solution. By removing the need for a large installation vessel, a towing method can help debottleneck project planning and simplify offshore logistics.
Fatigue Risk Management Plan for Existing Wells
Authors: Munipalli Jayanth , Lang Donogh 
Published: March 2018

Abstract
Due to increased demands, large BOP/LMRP systems are being deployed the world over, which has been raising concerns on the fatigue performance of wellhead systems, especially for existing systems for workover or P&A activities. While there have been low instances of such failures recorded globally, it is nonetheless accepted in the industry as a key concern and needs to be addressed. This paper discusses the various methods that can be adopted to help reduce fatigue damage on the existing wellhead and conductor systems involving both pre-operations engineering assessments and on-going active fatigue risk management processes.

Background
The authors through their significant experience in assessing fatigue damage in subsea wellhead and conductor systems in various regions globally, are presenting this paper to share some of the learnings and also describe the various mitigation methods available to reduce the conservatism in fatigue damage computation, enabling safer decision making upon re-entry on existing wellhead systems.
This paper uses background experience gained over the last three years in streamlining the process and developing a fatigue risk management plan which can be readily used by operators to address a key safety concern.
Flexible Pipeline: The Enabler for Brownfield's EOR Project
Authors: Jaafar Azam Syah , Ramli Nina Adrianna , Karim Khairul Anuar , Razak Siti Aishah Ali Noor , Ali M Nazmi M , Yunus M Jeffri M , Savy Pierre 
Published: March 2018

Abstract
Flexible pipeline is a technically and economically viable solution for brownfield's EOR project, and with reference to one of PETRONAS Carigali's recent EOR projects, is the enabler for this EOR development. This paper provides a review of available pipeline solutions to fulfill EOR project's gas and water injection requirements which are vital to the success of the EOR technology implementation.
A comprehensive technical assessment addressing the risk, advantages, limitations and also a brief overview on cost benefits have been performed on selected unconventional pipeline technologies, in comparison to rigid pipeline, using one of PETRONAS Carigali's recent EOR projects as the field case study.
The EOR project case study key design drivers and constraints, mainly the ultra-shallow water depths ranging between 8m to 50m LAT, congested seabed with existing infrastructures, large areas of coral outcrops at multiple locations and the relatively high design pressures and design temperatures present great challenges in choosing the optimum pipeline solution.
Feasibility of available unconventional pipeline technologies are evaluated against the project design drivers and the most viable solution is compared to the conventional rigid pipeline solution. Considerations are also given to design complexity, installation requirements, operation and integrity management. Complete selection criteria and matrixes are provided and supported with market information.
Dynamic Integrity Management of Flexible Pipe through Condition Performance Monitoring
Authors: Escuer Clara , Mahieu Camille , Sicsic Paul 
Published: March 2018

Abstract
Flexible pipe systems offer operators a robust method of producing oil and gas fields in harsh environments. The design of the flexible pipe is made according to international standards and internal rules to enable them to withstand the required loadings with a sufficient margin of safety. As these flexible pipes are key components of the field architectures, continuously assessing their integrity allows improved management of system risk and operability. The objective of this paper is to detail how Condition and Performance Monitoring (CPM) of the flexible risers enables a dynamic integrity management strategy.
Leveraging existing sensors, specific to the flexible pipe or for the overall production system, the integrity through specific failure modes is monitored. This implementation of CPM for flexibles is based on a set of complementary modules such as respect of design envelope, ageing of polymeric layers, annulus monitoring and fatigue of metallic wires. Actual and measured data - e.g. dynamic, thermal and pressure loading – reduce the uncertainty on these assessments with respect to design. Proper technical knowledge of the flexible pipe behavior allows monitoring of the underlying degradation mechanisms.
The information gathered from sensors is analyzed through specific algorithms for the flexibles linked to the CPM platform, allowing the user to visually see the results of the assessment. These data may also reflect possible human errors. This allows an early assessment of gaps (if any) between calculations performed at design stage & actual condition on the field, once these gaps are analyzed, flexible risers potentially at risk could be identified. To address the identified risk, on a case by case basis, specific inspections can be triggered or mitigating measures taken. By monitoring known failure mechanism, the probability of downtime is consequently reduced. Furthermore, the remaining life calculation on the equipment is more accurate with reduced uncertainties triggering more robust life extension decisions.
This paper demonstrates how an automatized use of the data from sensors allows for dynamic and optimized integrity management. This paper also demonstrates the added values in monitoring integrity of flexible pipes for OPEX (OPerational EXpenditure) optimization and to minimize offshore interventions.
Integrating an RBI Approach for Vibration-Induced Fatigue into a Mechanical Integrity Programme
Authors: Crowther Paul , Loneragan Bruce 
Published: March 2018

Abstract
Vibration-induced fatigue accounts for more than 20% of process piping failures. This integrity threat is often not addressed as part of traditional mechanical integrity programs.
Most vibration-induced fatigue failures can be prevented using a proactive, risk-based inspection (RBI) and assessment approach. The goal of this paper is to show how such an approach can be synergistic and integrated within existing mechanical integrity programs.
Facilities typically rely on plant operators to identify and report vibration problems. However, vibration issues can be hard to identify with visual inspection alone.
Vibration risks can be assessed using the Energy Institute's "Guideline for the Avoidance of Vibration Induced Fatigue Failure in Process Piping". The guideline can be adapted to streamline inspection programs and utilize the results during commissioning and operations.
This paper will illustrate how this guideline can be practically applied and integrated within conventional mechanical integrity programs, such as RBI programs used by corrosion engineers.
There is a gap between vibration studies carried out at the design stage and mechanical integrity programs of an operational plant. Due to perceived difficulties in the early detection of vibration problems, issues are often managed with a reactive approach. For example, in most cases, NDT does not discover vibration issues before they become critical.
To close this gap, a proactive, risk-based approach can be used to reduce vibration risks to acceptable levels before damage occurs. This is achieved through targeted screening and risk-ranking of critical locations, based on process and design considerations.
This approach allows for a cost-effective utilization of existing data from the design stage in order to support mechanical integrity programs during operations. The resulting vibration management database helps operators ensure vibration integrity throughout the asset lifecycle, eg, when changing process conditions or extending the lifetime of facilities.
Case studies will be used to illustrate how operators can effectively manage piping vibration risks for offshore assets, and how a risk-based approach can significantly reduce the time and costs spent on traditional vibration management.
The paper will illustrate how an effective screening process combined with innovative vibration data management can support operators throughout the facility lifecycle while reducing costs for integrity teams. The proposed process can lead to significant risk mitigations by providing actionable recommendations such as retro-fitting of supports, vibration-specific operating windows, design changes, and inspection plans targeted at high-risk areas.
Integrity inspectors, engineers and facility managers will benefit from this paper and learn how to manage vibration- induced fatigue failure risks more effectively.
Full Scale and Small Scale Qualification Tests of Mechanical Lined Pipe MLP for High Temperature Application Under HPHT and High H2S Services
Authors: Razak M Hasbi A , Malik Noor Syamiza Abdul 
Published: March 2018

ABSTRACT
A new gas field development with a challenging environment i.e. high pressure, high temperature and high H2S. The corrosion rate prediction performed, the expected metal loss is more than 8 mm thickness reduction within the 25 years design life. PETRONAS has embarked its tailor made qualification tests for qualifying CRA (Alloy 825) Mechanical Lined pipe to its project development. This is the pioneer project for PETRONAS to accommodate high pressure and high temperature service applications with high H2S environment. The tests were carried out to assess the susceptibility of liner material Alloy 825 to wrinkle under carbon steel pipeline coating condition, installation strain and operation strain, as well as to study the fatigue cracking behavioral at the seal weld locations due to operational cycles.
Challenges in Avoiding Sigma Phase Embrittlement of Duplex Stainless Steel in Assets
Authors: Ong H. G. , Yeap A. 
Published: March 2018

Abstract
The use of duplex stainless steel has been increasingly common in the oil and gas industry since the material offers a unique combination of high strength and superior corrosion resistance. However, the material is not immune to failure. A process safety incident at Sarawak Shell Bhd. highlighted this fact, whereby a duplex stainless steel gas flowline flange had fractured and parted after around 11 hours upon being installed and put in service. Independent failure investigations revealed that the failure was due to the formation of harmful sigma intermetallic phase in the base material of the flowline flange, a phenomenon known as sigma phase embrittlement. This can occur due to incorrect heat treatment processes during the manufacturing stage of duplex stainless steel components or due to incorrect welding processes. For the specific example reported in this paper, it was concluded that the flange was subject to incorrect heat treatment during manufacturing which exposed it to slow cooling through the sigma phase formation temperature range. This resulted in a significant loss of toughness and ductility of the flange material, which caused it to fracture and part shortly after being placed in service. Actions were subsequently taken to identify the risks of other duplex stainless steel piping components in Sarawak Shell Bhd. having the similar in correct heat treatment and thus could likely be subject to the same failure mechanism. This paper presents how a systematic risk-based approach was implemented to verify existing installed piping components in terms of their risks to intermetallic phase embrittlement. Actions taken to prevent similar occurrences in the future are also detailed. Ferrite count verifications using portable ferrite scope instruments were found to provide a useful screening method for verifying the likelihood of the presence of sigma phase in duplex stainless steel material. During procurement of duplex stainless steel components in new projects, inspection Hold Points for ferrite scope inspections were specified and implemented in the Inspection and Test Plans. Additionally, 100% ferrite scope inspections were imposed on all duplex stainless steel piping components received at Sarawak Shell Bhd.'s supply base warehouse. The procurement process for small quantities of duplex stainless steel components was revised to ensure that proper review of the technical specifications is carried out prior to placing purchase orders especially with stockists.
Use of Premium Connection to Justify Avoiding Pressure Testing Completion Tubing Prior to Setting Packer. Is this Always Correct?
Authors: Damasena Edwin , Arifin Muhamad , Ghaffar Fahmi 
Published: March 2018

Abstract
Pressure testing completion tubing prior to setting the production packer has been an accepted procedure in the past. However, over the years, complications and time (cost) to run a plug (on slick line) in high angle wells plus the advent of premium tubing connection and use of torque-turn monitor has made that practice almost redundant. Reliance on a metal to metal seal provided by premium connection, mill end quality control and tubing thread inspection are the main reasons for avoiding completion tubing pressure test prior to setting production packer.
This paper described the painful recovery, costing over US$ 4.8 million from a tubing connection leak despite the use of premium connection and torque-turn monitoring system. Troubleshooting the location of the leak is time consuming. Is the packer leaking or any of the completion components or the tubing leaking?
In this case one of the 13 Cr completion tubing connection was leaky. The completion string had an Integral Tubing Conveyed Perforation gun below the retrievable packer so it was time consuming and risky to retrieve tubing completion with a life gun. Over 40% of tubing had to be rejected due to galled thread when the completion was pulled.
A description of field trouble shooting the leak location is described. Analysis of the torque -turn graph and reasons for imperfect tubing make up causing the leak are discussed. Simulating field make-up process at the Yard and pressure testing the made-up premium connection are described. Lessons learned are presented.