bluuebunny/crossref_metadata_2025_split huggingface dataset:
Preliminary observations on artificial fecundation, hatching and developmental stages of embryo and larvae of the Indian shad Tenualosa ilisha (Hamilton, 1822)
Authors: Chattopadhyay D.N. , Chakraborty A. , Ray P.K. , Jayasankar P. 
Published: August 2019

Hilsa Tenualosa ilisha (Hamilton, 1822), one of the important commercial fish species in South Asian countries has received much attention for its conservation through captive breeding and seed production. The present study attempted to breed the fish by dry stripping in river Hooghly. Eggs were incubated at 22.8 and 28.30C temperatures in estuarine, pond and tap water. The hatching rate recorded was higher (p<0.05) in pond water (88-96%) compared to estuarine (70-76%) and tap water (72-74%) at both temperatures tested. Incubation period (19-22 h) and hatching rates in the three water media were not influenced by tested temperatures. Hourly changes in embryonic development till hatching and daily changes in 0-10 day old larvae are described in this paper.
Reproductive biology of Charybdis (Goniohellenus) longicollis Leene, 1938 (Brachyura: Portunidae), in the north-eastern Mediterranean Sea, Turkey
Authors: Tureli Canan , Yesilyurt Irem Nur 
Published: August 2019

The swimming crab, Charybdis (Goniohellenus) longicollis Leene, 1938, is a Lessepsian migrant into the Mediterranean and little is known about its biology in Iskenderun Bay, north-eastern Mediterranean, Turkey. The size of crabs, sex-ratio and spawning period of this species was defined from 951 specimens in order to understand their reproduction and development in the NE Mediterranean Sea. The crabs were found to occur throughout the year. Carapace width (CW) ranged between 7.22 to 100.60 mm and total weight ranged from 1.34 to 164.09 g. Male-female sex ratio was 0.6:1. Highest gonado-somatic index (GSI) was seen in March and September for females and in May for males. Ovigerous females were present throughout the year, with peak spawning activity in July and September. The CW of the ovigerous female crabs ranged between 23.71 and 95.93 mm. In winter months, GSI of males and females decreased. However, spawning season of C. (G.) longicolis in Yumurtalık Cove was observed throughout the year.
Environmentally Friendly Subsea Pipeline Decommissioning
Authors: Fielder Daniel , McGarry Rory 
Published: August 2019

Abstract

Objectives/Scope
Subsea pipeline decommissioning for either abandonment or retrieval is hazardous for both divers and the marine environment. This presentation reports on the development of a Fast Intervention Tool (FIT) for pipeline decommissioning by Webtool with input from Chevron Energy Technology Company. The FIT reduces the risks to divers and enables a quicker operation while avoiding the need for a containment dome during pipeline cutting and retrieval.

Methods, Procedures, Process
Sophisticated measures are taken to reduce the hazards to divers and the impact on the marine environment during pipeline decommissioning. Yet, traditional cutting technologies can undermine these best intentions. Diamond wire or other types of saw are time consuming and prone to jamming as the pipe moves during the cut. The containment dome used to catch contaminants that leach out during cutting and retrieval cannot "follow" the pipe as it is retrieved via a crane, therefore additional measures are needed to plug or seal to the pipe end before retrieval. The Fast Intervention Tool presented here addresses these shortcomings.

Results, Observations, Conclusions
The FIT combines lifting, crimping, injection and cutting in a single deployment frame which also contains the hydraulic control system. Deployed using a barge crane, the FIT assembly is lowered over a pipeline on the seabed, with either a diver or ROV to position it. The FIT cycle time to lift, crimp, inject sealant and cut is under 1 hour (excluding vessel or set up time) after which the pipe can now be safely recovered topside without leakage. The spike injector and blades will perform a number of cycles, therefore running costs are low; the only major consumable cost is the sealant itself. Webtool has completed FIT conceptual design and in-house development and testing and is now preparing a working prototype for hyperbaric and sea trials.

Novel/Additive Information
Safer and more environmentally friendly method of pipeline decommissioning.
Challenge of Temperature Control for Downhole Instruments in HTHP Reservoir
Authors: Gao Wenkai , Liu Ke , Jia Hengtian , Hong Difeng , Teng Xinmiao 
Published: August 2019

Abstract
With the further exploration of oil and gas, we have to search for new resources which buried in deep strata, and most of the deep and ultra-deep wells are categorized in high-pressure/high-temperature (HPHT) wells. The problem of high temperature and the challenge to the existing downhole equipments are becoming increasingly prominent, where the drilling depth is severely restricted. The conventional measurement while drilling tools with common electronics will experience very high failure rates at these conditions.
One of the solutions is called the active cooling technology, which can transfer the heat from electronics system to downhole environment. By this way, the temperature control of downhole instrument circuit system is realized.
The active cooling technology is expounded in this paper, expecially about the principles and development status of each system. After evaluating and analyzing the characteristics of this technology, the function of heat transfer and constituent elements for the cooling system are summarized.
The study from this work demonstrates the future work for downhole cooling technology: large refrigeration capacity, small size, strong adaptability and modularization.
Adaptive Artificial Neural Networks for Water-Cut Estimation Using Near-Infrared Optical Sensors
Authors: Li Qin , Fjalestad Kjetil 
Published: August 2019

Abstract
In this paper, we present a water-cut estimator utilizing the function approximation capability of an artificial neural network (ANN). The inputs to the ANN are optical sensor readings in a Red-Eye water-cut meter, which features the near-infrared (NIR) absorption spectroscopy technology. The initial training of the ANNwas done with a data set acquired from our multi-phase flow-loop test facility, which was filled with live oil, water and gas. The test fluid stream was adjusted with good ranges of water-cut and gas-volume fractions which were supposed to cover the situations that can be foreseen in real production. However, clear discrepancies between the outputs of the ANN and the water-cut values from BS&W measurmentswere observedwhen the ANN was applied to actual production data measured by Red-Eye meters installed at two offshore wells. To address this issue and equip the ANN with self-adapting capability in real application, we propose a Bayesian approach to update the parameters of the ANN based on both initial flow-loop data and collected field data. The performance of the adapted ANN on both the data sets shows the effectiveness of the method.
Unlocking the Full Potential: The Psychological Factors that Influence the Adoption of New Technologies in the Upstream Oil and Gas Industry.
Authors: Roberts Ruby , Flin Rhona , Millar David , Corradi Luca 
Published: August 2019

Abstract
Innovation is critical to the future success of the oil and gas industry. Yet, the sector has a reputation for being conservative and reluctant to adopt new technology with companies sometimes referred to as "fast followers". Compared to other sectors, O&G has a set of unique characteristics that has the potential to hinder technology adoption. Research in other industries indicates that there is a range of sector, organizational and psychological factors that can hinder the introduction of new technologies. Evidence from O&G industry bodies indicate that the psychological factors play a key role in technology adoption; not surprisingly, as workers, managers, investors and regulators can all have a powerful influence on an organisation's receptivity to new technology. The psychological factors do not appear to be well understood but may include risk aversion (Wood Review, 2014), lack of ownership and leadership around technology (OGTC, 2018), and an attitude of reluctance to change (Oil and Gas Authority, 2018).
This new research project is designed to examine how the particular attributes of the upstream oil and gas industry on the United Kingdom Continental Shelf interact with the underlying psychological processes that govern adoption and deployment decisions. The presentation will first outline what can be learned from about the psychological factors that influence technology innovation and adoption from the broader consumer behaviour and human factors literatures. Then the preliminary results of an interview study with stakeholders involved in technology innovation and adoption on the UKCS, will be reported. Roles include senior managers, innovation leads, and end users from a spectrum of established and new comer companies. A summary of the key themes identified will be discussed including personality (e.g. innovativeness), attitude (e.g. risk aversion), cognitive (e.g. risk perception), social (subjective norms) and organisational level factors (e.g. leadership and organisational culture). These results are being used to develop a preliminary framework of the psychological factors that influence technology adoption in O&G and to produce tools and guidelines on how to support the introduction of new technologies.
Improving Performance in Elgin HPHT Infill Drilling Despite Increasing Challenges
Authors: Alahmad Mohammad , Eatough Oliver 
Published: August 2019

Abstract
Following the significant reservoir depletion on Elgin / Franklin fields since 2007, drilling infill wells was considered to not only be high cost but also carry a high probability of failure to reach the well objective. The recent campaign on the Elgin field, one of the most heavily depleted reservoirs worldwide, demonstrated that infill drilling can be achieved safely while improving performance.
Drilling of HPHT infill wells on the Elgin field faced increasing challenges arising from the reduction of reservoir pressure that changed the stresses in the formations above and influenced the overall pressure regime. This stress reorganization in the overburden has affected the fracture network in these formations resulting in reduction in Fracture Initiation Pressure (FIP) and increase of gas levels.
Challenges were faced during the drilling of three wells in the 2015-2017 campaign. Loss events in Chalk formations in the intermediate sections significantly decreased the already Narrow Mud Weight Window (NMWW). A strategy to define and validate the minimum required MWW in 12-1/2" and 8-1/2" sections was developed following a complex subsurface well control event. Managed Pressure Drilling (MPD) technique was extensively used to safely manage gas levels and assess pore pressure.
Reservoir entry with more than 850 bar of overbalance remains the main challenge in infill drilling. A total loss event during first reservoir entry in the latest campaign confirmed the limitations of wellbore strengthening mud and stress caging materials available today.
Lessons learned from each well in this campaign were implemented to address these challenges and improve performance. This paper describes the Elgin HP/HT infill drilling experience and the specific techniques and practices that were developed to address these challenges and improve performance. The importance of Equivalent Circulating Density (ECD) management with very narrow MWW, successful high gas level management with MPD and depleted reservoir entry, shows that even in a highly complex environment, drilling performance can be improved allowing for further economical development drilling. The successful and safe delivery of the Elgin 2015-2017 infill drilling campaign demonstrates this at a time the industry moves toward unlocking the reserves of more challenging HPHT fields.
Risk-Based Approaches for Planning the Inspections of Large-Scale Topside Structural Systems
Authors: Faridafshin Farzad , Anvari Majid , Hellevig Nils Christian 
Published: August 2019

Abstract
Life-cycle safety and integrity management of offshore structures is a critical activity owing to the adverse consequences of structural failure, ranging from loss of life and financial consequences to environmental pollution.
Historically, integrity management of substructures such as jacket structures has been the subject of more detailed investigations than the integrity management of topside structures. For instance, more specific risk- and reliability-based methodologies exist for integrity assurance and planning the inspections of jacket structures than for topside structures. This article presents a practical methodology for risk-based inspection planning of large-scale topside structural systems under different limit states (ultimate, accidental, fatigue, and serviceability) and degradation mechanisms (e.g., corrosion and fatigue crack growth), with a view to data analytics and digitalization.
The main advantage of the presented methodology is in its capability in systematically ranking the different structural elements/areas relative to one another based on their assessed level of risk of failure, i.e. a risk-based differentiation, and planning the inspections and repairs accordingly for large-scale structural systems. Such an integrated approach will result in efficient and economical management of offshore topside structural assets and can be used as a consistent and coherent basis for lifetime extension or decommissioning of offshore platforms.
Integrity management of offshore structures is known to involve the analysis and management of large amounts of data and information over the lifetime of the structure. Therefore, insights are provided in the article regarding how the presented risk-based methodologies can be integrated into a digitalized and data-driven interface—a topic currently under heated investigation across the petroleum industry, facilitating the analysis and management of the involved data and information in an efficient and verifiable manner.
Cost Effective, Reduced Trip Completions? Problem Solved
Authors: Robertson Bruce , Murdoch Euan , Ojeh-Oziegbe Osehojie 
Published: August 2019

Abstract
It is often stated that necessity is the mother of invention. Never is this proverb more relevant than in the offshore oil and gas environment we currently operate in where real step changes leading to reduced capital and operational expenditure opportunities are sought and embraced by field operators. This paper discusses the pre-job planning, field execution and lessons learned from one such technology that challenged conventional thinking of sand faced completion, casedhole completion and well integrity to successfully deliver a single-trip, interventionless, sand control completion in deepwater Bonga Field, located on the continental slope of the Niger Delta.
Convention dictates that the vast majority of offshore completions be run in two and sometimes three trips which routinely takes in excess of eight to ten days to deploy. Given the day rate of high specification rigs capable of drilling in deep water environments, the ability to reduce this time was deemed paramount to the economics of the project. Utilizing a collaborative approach to initial concept design, risk assessment, extensive testing and contingency planning at component and system level, a single-trip, interventionless, sand control completion system was designed and successfully installed. This paper describes the completion architecture, operational sequence and challenges leading to the installation of an interventionless completion.
A clearly defined set of deliverables and design principles were drawn up to guide the direction of the project including: successfully deploying the upper and lower completion in one trip, and testing all barriers. Adopting a simple, low risk and high reward design, meeting clients well barrier requirements and utilizing proven cost-effective technology are examples of design principles used. The system was tested and evolved through a number of iterations in an onshore trial well environment on a number of occasions leading to the first successful deployment completed in the second half of 2018, resulting in an average completion installation time of 5 days, versus the average 10 days for deploying multi-trip completions. Details of the successful installations, lessons learned, along with planned future activity are outlined within the body of this paper. While several of the components incorporated in the single-trip system had been run previously in isolation, this paper also discusses the steps taken to facilitate the first full-system approach to the application of radio frequency identification (RFID) enabled tools in the first single-trip, interventionless sand control completion system. Several components within the completion have been equipped with this technology including a multi-cycle ball valve, wire wrapped screens fitted with inflow control device (ICD), remote operated sliding sleeve for annular fluid displacement.
Digital Worker: Empowering Offshore Operators with Easily Accessible Data to Improve Efficiency and Safety
Authors: Aadland Aadne , Straumsheim Carl Fredrik , Giset Aksel 
Published: August 2019

Abstract
Digitalization is the transformation of business models and activities through the strategic use of digital technologies. Despite technological advancements in machine learning (ML), artificial intelligence (AI), and virtual reality (VR), there remains a low maturity of digitalization across the oil and gas industry, especially in offshore operations. There are many roadblocks on the way to digitalization, from data silos to legacy systems. Operational inefficiency is one of the most painful byproducts of these problems.
To complete a single maintenance task, for example, on-site workers may need to access several separate systems to get the required data. They rely on printing out the information they need in order to complete the maintenance activities, and after taking notes on pieces of paper, they have to return to their desktop computer to log the performed tasks.
Not having the data readily accessible contributes to overall inefficiency, and offshore workers often run back and forth while performing maintenance tasks, increasing the hours they spend in challenging conditions.
This paper will outline an application design philosophy for oil and gas companies that combines academic and practical insights, an emphasis on continually testing products in development, and an overall goal of creating value.
This paper will describe how a Nordic software company is using the design philosophy to help an oil and gas operator in Northern Europe optimize on-site operations -- including increasing efficiency and safety -- on its offshore installations on the Norwegian Continental Shelf.
Specifically, the paper will show the software company ingested and contextualized operational data from the operator's assets and made historical data available for field workers via an application for computers and smart devices. This included access to sensor data and historic equipment performance data; all documentation related to maintenance, including procedures, drawings, piping and instrumentation diagrams (P&IDs), and maintenance logs; and interactive 3D models of installations and equipment.
After only three months, the crew at one of the operator's oil installations saw significant increases in the number of monthly maintenance jobs (up to 10% for certain tasks) and reduction of the time spent on certain routine inspections (in some cases up to 50%).
Improving the Quality and Efficiency of Operational Planning and Risk Management with ML and NLP
Authors: Birnie Claire Emma , Sampson Jennifer , Sjaastad Eivind , Johansen Bjarte , Obrestad Lars Egil , Larsen Ronny , Khamassi Ahmed 
Published: August 2019

Abstract
To ensure safe and efficient operations, all offshore operations follow a plan devised to take into account current operation conditions and identify the optimum workflow with the minimum risk potential. Previously, planners had to manually consult eight data sources, each with a separate UI, and summarise the plan in a.pdf document. Equinor's Operation Planning Tool (OPT) has been developed to easily present the planners with the technical conditions of a platform, identify potentially dangerous combinations of concurrent activities, and propose learnings from eight years’ worth of incident recordings – all relevant to the current list of planned activities. The tool aims to answer questions such as ‘are other activities planned for the same time which would make this activity unsafe?’ or ‘have incidents previously occurred whilst performing similar tasks on this equipment type?’.
This paper details the development of the OPT with a particular focus on the application of Natural Language Understanding for extracting equipment types and tasks involved in previous incidents and relating these to planned activities. Utilising natural language processing techniques, a system has been developed that mines the content of Equinor's incident database, and assigns context to incidents, by identifying the systems, activities and equipment involved and the conditions on the asset at the time of the incident. The same context is also discovered from the content of planned activities. These key concepts are organised into a knowledge graph synthesising Equinor's institutional safety and operational experience.
The OPT has reduced time spent planning by providing a single interface detailing a plant's technical conditions, all planned work orders and relevant lessons learned from previous incidents. By reducing the reliance on personal experience, the tool has provided subjectively improved risk identification and handling, plus faster knowledge transfer to new employees as well as focussed cross-platform knowledge sharing. The success of the tool highlights the strength of combining data and leveraging the vast quantities of historic data available both in unstructured and structured forms to create a safe, offshore work environment.
The Subsea Pipeline Inspection Paradigm - What Next ?
Authors: Shand Calum 
Published: August 2019

Abstract
Shell in the UK has a vast network of more than 200 pipelines & umbilicals covering some 3000+ kilometres. Historically, Shell has executed Side Scan Sonar Surveys along these pipelines using a Remotely Operated Towed Vehicle and subsequently followed up with ROV based surveys & inspections. However, in 2018, the respective Geomatics & Subsea Maintenance / Pipelines Departments decided to take advantage of new & emerging innovative technologies and compiled a minimal technical scope & tender document to tap into the latest that the market could offer. Consequently, Shell UK awarded DeepOcean (Norway) with a contract for their "Fast Digital Imaging Service" and embarked on a 45 day survey campaign. In 2019, the same subsea inspection project will be executed once again and the lessons learned ought to inspire and excite many different disciplines and communities, both internally within Shell and externally e.g OGA - Oil & Gas Authority & other valued stakeholders.
The paper highlights the key technologies that were deployed and how the new deliverables & business insights take us down the road to Digitalisation including scope for future Machine Learning & Automation processes. Challenges arising from the acquisition and managing the associated data sets shall also be discussed. The speaker will spark dialogue at the end by asking the respective communities how robotics and artificial intelligence will change the industry landscape ?