bluuebunny/crossref_metadata_2025 huggingface dataset:
Temperature Maintenance Philosophy to Optimise Electrically Heated Flowline Solutions
Authors: Alexis Wegner , Geraldine Trucy , Guy Mencarelli , John Leitch , Christian Geertsen , Geraldine Salque
Published: April 2020

The design of an electrically heated flowline is based on several thermal requirements, which significantly affect the design and the CAPEX of such a solution. In particular, the heat-up criteria which define the minimum duration - usually 48 hrs - required to heat-up a flowline from ambient temperature to the ready-for-restart temperature is often the most demanding one and drives the electrical system requirements in a very conservative way compared to the other heating criteria. The objective of this paper is to demonstrate how the industry could remove this heat-up requirement and adopt a "temperature maintenance operating philosophy" to optimise the design of electrically heated flowlines. Heat-ups from ambient temperature would still be achievable, in less than seven days.

This approach is particularly well suited to heat traced pipe-in-pipe, where the heat lost to the environment is extremely low. For these highly insulated flowlines, the temperature maintenance duty power is significantly reduced, compared to the required power for heat-up phases.

This paper investigates the potential benefits and the feasibility of this change in the design requirements. Initially, impacts on the overall heated flowline design and particularly on the electrical architecture have been assessed as well as the associated CAPEX reduction. Secondly, analyses of the corresponding operating procedures have been conducted to assess feasibility. Finally, OPEX aspects have been taken into account to conclude on the overall interest of the solution.

Case studies show that applying a temperature maintenance philosophy to heat traced pipe-in-pipe would lead to significant CAPEX savings thanks to optimised electrical system design. Regarding shutdown costs, although the results depend on the assumptions considered, the temperature maintenance philosophy appears preferable as it results in lower power consumption and shorter shutdowns, the majority of the time. Furthermore, fewer heat-up phases result in safer procedures with regard to hydrate melting risks while reducing the power applied reduces the electrical stress on the heating system.

All the assessments have been conducted based on Electrically Heat Traced Flowline (EHTF) technology however the same exercise could be performed for other electrically heated flowline technologies and could demonstrate similar benefits.
Tango FLNG - From Contract to Production in Less than 6 Months
Authors: Van Nuffel Frederik , Krekel Max , Verhagen Joris , Gilbert Thomas
Published: April 2020

Argentina is evolving from a natural gas importer to an exporter, thanks to the development of the Vaca Muerta formation in the Neuquén Basin. The Argentinean National Oil Company is still ramping up production, but already there is excess gas available for export in the form of LNG to international markets. The Caribbean Floating LNG (CFLNG) barge had been completed for another project, which unfortunately had been cancelled due to bankruptcy of the Client. In August 2018, the two companies met ‘over a cup of coffee’ to see if CFLNG could be deployed as a pilot production system for LNG export in Bahía Blanca, Argentina.

CFLNG was designed as a small-scale liquefaction system of 0.5 MTPA capacity, using pipeline quality feed gas. The paper will describe the design considerations made at the time, as well as the Engineering, Procurement, Construction and Commissioning activities to complete the unit for its alternate feed gas and location. Especially the latter was a major undertaking, since validating CFLNG’s liquefaction performance comprised loading 270 road trailers LNG into its cargo tanks, installation of a temporary LNG vaporization skid, to be able to complete the contractual full 72-hour liquefaction performance test, all while docked quayside at the construction yard.

Also, the paper will address the modifications made to the unit to moor it alongside an existing jetty in Bahía Blanca, to receive gas from shore, as well as the provisions made onshore for pre-treatment and pressure boosting of the feed gas.

After the initial contact with the end customer, due diligence inspections and engineering studies were performed on how CFLNG could be deployed in Argentina. Soon, both parties realized the unit was a good match. A contract was signed on November 20th, 2018: Caribbean FLNG was now to become Tango FLNG.

Site specific modification and reactivation works were carried out in China, where the unit was laid up. It was loaded onto a semi-submersible heavy lift vessel (HLV) close to Shanghai, late December 2018. In parallel, gas treatment and compression equipment was sourced and procured, and modifications to the jetty were completed. The unit arrived in Bahía Blanca in February 2019. After mooring up, commissioning activities were started, ultimately resulting in the successful delivery of a first LNG cargo on June 6th, 2019. Noteworthy detail is that Tango FLNG is moored to the same Jetty that was used to import LNG to Argentina for 10 years!

The project demonstrates that the FLNG concept is flexible and can be redeployed to other locations. The Start-up of Tango FLNG is the start of LNG export for Argentina.
Fatigue of Slender Offshore Structures: Moorings, Risers, and Umbilicals
Authors: Wu Yongyan , Wang Tao , Vijayaraghavan Vishnu
Published: April 2020

Fatigue is one of the key design considerations for moorings, risers, and umbilicals in offshore floating systems. Due to differences in materials, components, configurations, and functionality, these slender structures have distinct drivers for fatigue performance. On the other hand, they also share a number of the same challenges. Typical slender structure design configurations include taut and catenary mooring systems; steel catenary riser, steel lazy wave riser; and catenary, lazy wave, and pliant wave configurations for umbilicals. This paper introduces the fatigue performance drivers for mooring lines, risers, and umbilicals. The paper also compares the fatigue performance of moorings, risers, and umbilicals, and provide cross-disciplinary guidance to the integrated design of floating systems, thereby helping improve the overall system reliability.

Moorings, risers, and umbilicals demonstrate quite distinct fatigue characteristics but share some similar challenges. Mooring fatigue performance is influenced by tension and corrosion. Chains in fairlead locations and on the bottom are the most critical fatigue locations for mooring fatigue. Recent fatigue test data show that mean tension significantly impacts chain fatigue and thus whole mooring system fatigue life. Fatigue is a significant challenge for riser design due to tension and bending. The hangoff and touchdown zones are usually the most fatigue critical areas for risers as well. Similar to the mooring design, corrosion contributes to riser fatigue. Riser configuration, internal fluid slugging, as well as seabed stiffness significantly affect riser fatigue performance. Besides tension and bending, one of the specific features for umbilical design is the interaction between the different elements within an umbilical cross-section, which significantly impacts its life. Since this effect is more significant in regions with higher tension and curvature, the hang off region is usually the critical area for umbilical fatigue.

The offshore industry is moving towards integrated design and systematic approaches. Although there is abundant literature discussing the fatigue of mooring, risers, and umbilicals separately, there is very limited published literature comparing the performance of these three types of slender structures. This paper can serve as a useful reference for a floating system integrated design. Cross disciplines can also benefit by leveraging the design philosophy and mitigation strategy of different types of slender structures.
Experience with Active Flow Assurance
Authors: Iversen Øyvind , Blystad Jørgen
Published: April 2020

Following the drop of oil prices during 2015 we have seen an increased attention from operators on using new technology, in particular active heating technologies. This paper presents an update to experience from early implementation with lessons learned to recent technology development of what today is the only field proven electric heating technology for rigid flowlines per today - Direct Electric Heating (DEH). It also discusses Electric Heat Tracing as promising technology undergoing qualification – but the main focus is on DEH.

DEH had its technology qualification carried out in the 90-ties and early 2000's while the more recent years has focused on achieving long distance tie backs, qualification for deep water projects but also design alteration opening for cost reduction.

Increased number of operators:

During the first 10 years, all projects were in operation in the North Sea whereas during the last 8 years other operators has started using the technology, as well as applications in harsher environment and deeper waters.

Deep water:

Following internal testing to gain more information on material data of steel and copper, combined with an update in analysis technique – previous over-conservatism in design process can be reduced such that a more accurate analysis can be carried out. Consequently, cable designs which previously only were applicable for depths down to less than 800m WD can now be used at 1500m WD.

Long distance step-outs:

Wet design XLPE insulation to higher electrical gradients has been now successfully qualified, allowing DEH to be applied on longer distance tie-backs than before

Technology improvements

A 3-year R&D on high frequency DEH gives both technical advantages for interference with other subsea equipment, reduced AC corrosion as smaller conductors which leads to a significant cost reduction.

With the above technical improvements alone or combined, and a better DEH system than that was qualified in year 2000 is now available to the market.
A Comparison of Stakeholder Engagement Strategies for Offshore Decommissioning Projects in the United Kingdom and Australian Landscape
Authors: Tung Aaron
Published: April 2020

Stakeholder engagement is a critical element in offshore decommissioning projects. If stakeholders are engaged well, it can bring benefits to the decommissioning project through cost reduction, improved scheduling, and improved relationships. However, if stakeholders are antagonized, the influence and impact of these stakeholders will not only affect the operating company alone, but the entire oil and gas industry as well.

Stakeholder landscape varies from location to location. In the United Kingdom, and also in the Bass Straits of Australia, commercial fisheries and trawlers have a significant lobby which can potentially derail any offshore activities. In other areas such as the North-West Shelf of Western Australia, recreational fisheries tend to be more influential than other stakeholders (Askew & Lea-Cox, 2017). In areas such as the Timor Sea, local communities are more concerned about the impact of offshore projects on their standard of living (Clyne & Jackson, 2014; Lundahl & Sjöholm, 2008). As such, it is important for operators to adapt their stakeholder engagement philosophies and strategies to suit different stakeholder landscapes.

Stakeholder engagement strategies can be anywhere along the visibility spectrum, ranging from low visibility targeted engagements (Phillips UK's Maureen, BP UK's Miller, CNRI's Murchison, Woodside's Balnaves, and PTTEP's Challis and Jabiru), to high visibility public events (BP UK's North-West Hutton, Fairfield's Dunlin, Shell's Brent). Holding high visibility events to highlight engineering feats and successes can improve the operator's recognition among its peers in the industry. However, the action, while not intended, may come off as arrogant, ignorant, and overbearing to public stakeholders outside the industry. In some cases, high profile events will only remind public stakeholders about past interactions and mistakes, highlighting how environmentally and socially impacting decommissioning projects can be.

The level of visibility of stakeholder engagement strategies for any decommissioning project depends on three factors: 1) Past stakeholder interactions, 2) Past media coverage, and 3) Amount of components with high environmental and social risks. For example, if a decommissioning project have a lot of past stakeholder interaction and media coverage, and a lot if environmental and socially risky components, then the ideal stakeholder interaction strategy should be more discreet and low profile.

As such, it is important for operators to be aware of the characteristics of their portfolio and assets when developing stakeholder engagement strategies.
Evaluating Offshore Rope Fibers: Impact on Mooring Systems Integrity and Performance
Authors: Bastos Milton Briguet , Silva Ana Lucia Nazareth
Published: April 2020

Objectives/scope

Polymeric Fiber Ropes have been used extensively for Permanent Offshore Deep-Water Mooring systems. High strength polyester ropes have been used for FPSO mooring with proven performance of more than 20 years. Fiber rope have no corrosion issues and superior performance in fatigue.

There is also a need to evaluate the applicability of fiber ropes instead of steel chains and/or steel ropes used on top and mudline segments.

Long-term performance and integrity with the benefit of a lower Total Cost of Ownership (TCO) can be expected. The OTC 24025 paper addresses integrity issues on permanent mooring systems. Authors concluded that a great majority of premature failures/damages are associated with steel components such as chain, wire ropes and connectors, and not with fiber rope segments.

It is also necessary to assess long-term performance and environmental resistance of synthetic rope regarding its use in top side, mudline, as well as shallow water mooring for the growing business of Marine Renewable Energy and Offshore Wind Farms (FOWT). It is also important to study the lifetime assessment of polyester mooring ropes.

FPSO operators are also considering life extension of existent mooring systems installed over 10-15 years ago evaluating the impact of creep, hydrolysis and other environmental issues such as UV and marine life growth.
Self-Certification and Safety Compliance for Robotics Platforms
Authors: Zaki Osama Farouk , Flynn David , Blanche Jamie Rowland Douglas , Roe Joshua Kenneth , Kong Leo , Mitchell Daniel , Lim Theo , Harper Sam Thomas , Robu Valentin
Published: April 2020

In this paper, the results and methodology of a framework to enable run-time safety compliance and self-certification of robotics is presented. This transferable framework is verified within a practical demonstration scenario, based on asset inspection within a confined space, and representing a Beyond Visual Line of Sight (BVLOS) use case. The methodology of the framework is based on computationally efficient analysis to support run-time, front-end, data analysis and adaptive decision-making. Utilizing the Husky A200 platform, manufactured by Clearpath, front-end datasets on the mission status and diagnostics of critical sub-systems within the Husky platform are used to update run-time system ontologies. The holistic and hierarchical- relational model of the robot integrates the automata of the sensed and some non-sensed components, using prior knowledge, such as risk assessments and offline reliability data, to support run-time analysis, such as fault prognosis, detection, isolation and diagnosis. These computationally efficient data and system analyses then enable faults to be translated into failure modes that can affect decision making during the mission. With respect to challenges of a dynamic environment, namely ambient conditions or the presence of unexpected people, Frequency Modulated Continuous Wave (FMCW) sensing is integrated onto the husky platform. The FMCW supports localization in opaque environments and detection of people within and out-with of the confined space, as well as enabling integrity analysis of the infrastructure. The framework presents its results within a symbiotic digital twin of the infrastructure and robotic platform. With fully synchronized communication and data streams, the interactive digital twin provides operational decision support and trust for human in the loop operators of varying skill levels. The presentation of actionable information to the end user is used to support improvements in productivity associated with asset integrity as well as supporting user trust in safety during a BVLOS mission.
Perfecting The ‘Perfect Well’: Lessons-learned From The Pre-drilling Campaign For Johan Sverdrup
Authors: Vølstad Janne , Bærheim Stian , Henriksen Knut , Gloppen Trond
Published: April 2020

The pre-drilling campaign for the Johan Sverdrup development was a key contributor to the successful execution of the first phase of the mega-project. The initial pre-drilling plan consisted of drilling six (6) oil producers, seven (7) subsea injectors and one (1) pilot target. At the end of the campaign, however, as many as eight (8) oil producers, twelve (12) subsea injectors and six (6) pilot targets had been drilled, more than one year ahead of the original schedule and NOK 7 billion (nearly 800 million USD) below budget. All the wells in the pre-drilling campaign were drilled by the semi-submersible drilling unit Deepsea Atlantic (Odfjell Drilling) and the objectives were met on all wells.

After a summary of the results of the campaign, the focus of this paper is to identify some of the key success factors behind the campaign and attempts to draw lessons-learned of relevance to future drilling campaigns. Key areas to be assessed in the paper include: contract strategies including the use of integrated service and rig contracts with common incentives to develop and maintain a "One-Team" mentality; the further development of the ‘perfect well’ approach and Lean methodology to minimize waste and maximize efficiency of the campaign; as well as efforts and arenas to systematically promote collaboration, openness and regular experience transfer among the different parties involved (operator and contractors).

Since the pre-drilling campaign was completed, the Johan Sverdrup project has successfully tied back, completed and started production of the eight (8) pre-drilled oil producers and injection in the twelve (12) subsea injectors.
The Success of Conducting First Offshore Well Drilling by Pertamina EP with Corporate Synergy
Authors: Noviaris Ahmad Burhan , Irawan Gondo , Sundja Ali , Nugroho Sapto Edi , Maaruf Pranefo , Abdila Sayid Faisal
Published: April 2020

Pertamina EP is an Indonesian national oil company which subsidiaries of PT Pertamina (Persero). For nearly 60 years, the Pertamina EP drilling area has been located onshore. In September 2017, Pertamina EP successfully conducted a Poleng N-2 well as the first drilling operation in an offshore area.

Originally wells candidate's Poleng N-2, proposed in early 2017 with the target of drilling operations can be carried out on TW-3 in 2017. However, considering the acceleration of production, utilities offshore rig availability and cost efficiencies, accelerated drilling operations into TW-2 in 2017. it begins with the efforts to accelerate drilling AFE approval Poleng N-2 of SKK Migas on June 15, 2017.

Short preparation was conducted with the support of SKK Migas and synergy of PHE WMO and PEP as a form of Pertamina Incorporated. Synergy is done in the form Farm in contract, Material Transfer Agreement and the exchange of information and expertise of each subsidiary, as well as support for QA / QC of internal WMO competent and experienced in drilling operations using Ensco Rig 67. So in the end, in the span of about three months, can be resolved about contract services and materials, including the preparation of internal HR by chance exposure PEP Drilling wells to WMO.

Poleng field located in East Java province started operated by Pertamina EP in 2013. The drilling program Poleng N-2 of the Platform CW as the first drilling operation PEP from this field is expected to increase the production of limestone reservoir targets Kujung. As for the design of drilling a sidetrack well from the well parent CW-02H, at a depth of 5,000 ft MD ± which has a horizontal well trajectory is quite challenging on the route hole the size of 6-1 / 8 ″in length ± 2500 ft. The well completion technology also comes with Inflow Control Device (ICD) and Swell Packer on 4-1 / 2 ″Liner as part of the Lower Completion.

In the end the Poleng N-2 well drilling operation can be completed in November 2017, with the status: Zero incident / accident, cost about 75% of the approved budget, the percentage of Non Productive Time is less than 5% and Initial production reached 783 BOPD above target of 700 BOPD so that production acceleration can be realized with a good economic level.
A Novel Way of Project Management to Ensure Engagement for Successful Digital Transformation.
Authors: Lamacchia Diego , Chowdhury Khairul , Sharif Omar
Published: April 2020

The cultural step-change for a successful digital transformation in the Oil & Gas industry is a significant struggle. Under the pressure of executing projects with a lower budget and in time during this low oil price era, project management becomes a complex challenge. In addition, the endeavor in digital technology imposes a transition from traditional project execution to agile project execution which makes the transformation even more challenging. Thus, the objective of this paper is to present a novel way of project management called "Open Project Management" (OPM) using a digital platform that helps team members and employees to engage in the digital transformation process using social networking technology.

The Open Project Management (OPM) approach is planned and organized to bridge the traditional project management (TPM) processes (plan-execution-control/monitoring-closing cycle), and the agile project management (APM) processes (short sprint iterations of planning-analysis-design-test-acceptance cycle), by focusing on the basic project building blocks: project deliverables. In the OPM platform, all project members and management processes are directly connected thru the project deliverables (either working packages or sprints). The OPM is flexible enough to switch between the traditional, the agile, or a blended approach. The open approach is aimed to empower employees by offering leadership through a self-management and ease execution work by sharing and collaborating with other project team members and project managers.

To implement the OPM approach, a digital collaborative workspace platform is built to mimic familiar social media networks so that employees can perform their work within the system with minimal training. The OPM platform is comprised of 3 frameworks: i) project management, ii) project visualization and iii) project communications. These three digital frameworks combinedly allow every member to work in a collaborative way within the platform by integrating their work process and get quick feedback.

The novelty of the OPM approach lies in creating autonomy, increasing transparency and more importantly engagement without face-to-face interaction for all stakeholders of the project execution. The OPM platform is an intelligent digital eco-system (iDES) that works like the traditional social media platforms, which allows employees bringing what they use in their personal lifestyle into work without adopting a new system. The workspace offers to create their work-image into the workplace, enhancing their motivation towards work and empower them. Such a project management strategy and the tool for successful implementation are essential to provide a transitional phase for employees to trigger the cultural step change required to implement digital transformation objectives.
Using a New, Autonomous, and Easy to Install Strain Sensor for Monitoring of Dynamic Loads on a Subsea BOP in Order to Reduce Conservatism and Increase Service Life of Subsea Equipment.
Authors: Holden Harald , Martinsen Vegard , Grønningsæter Åge
Published: April 2020

In recent years, monitoring of the subsea BOP in order to keep track of movements, loads, and fatigue accumulation on subsea wellheads has been performed. On the Norwegian Continental Shelf, more than 50% of the semisubmersible drilling rigs have equipment for measuring the motion and load on the subsea BOP. A typical setup is to have motion sensors installed and calculate the loads on the lower part of the BOP and the subsea structure from indirect methods where knowledge of system parameters such as tension, weights and drag coefficients is used to establish the loads. Direct measurement of the load using strain gauges or LVDT's has proven challenging due to time consuming installation, fragile measurement equipment, and difficulties finding suitable areas to mount the sensors.

The objective of this paper is to present a novel sensor technology that allows for accurate measurement of strains in a wide measuring range. In contrast to existing measuring equipment this new sensor technology enables a compact, robust, and easy to install strain sensor. The new sensor is small enough to be mounted behind the bolts/ nuts on an 18 ¾″ BOP flange neck. The sensors can be used to increase the accuracy and reduce unnecessary conservatism in the measured wellhead loads. This can again reduce the need for expensive load reducing measures or disconnects.

This paper will present the core principles of the new strain sensor. Laboratory tests showing the performance and accuracy of the sensor will be shown, and the benefits of this sensor versus existing technologies will be demonstrated.

The introduction of this new sensor enables direct measurement of the loading on the subsea wellhead system. The new measuring process will be presented and compared with the traditional indirect measurement process. This comparison will illustrate where in the measuring process increased accuracy and reduced conservatism can be achieved, and then quantifying the improvements.

Further, the paper will present results from use of the sensor in actual measurement campaigns from drilling operations in harsh environment on the Norwegian Continental Shelf.

The paper will present the findings from the first measuring campaigns using this new sensor technology. The measured results will be compared with the traditional indirect measurement method and the improvement, in terms of reduced conservatism and increased accuracy, will be shown. Then finally, the consequence in terms of reduction on measured extreme and fatigue load, will be presented.

This paper will show how new sensor technology can be used to obtain more accurate and less conservative measurements of the loading on a subsea wellhead system in order to reduce the need for expensive load reducing measures.
Leveraging Systems Engineering to Effectively Reduce Certification and Qualification Cost and Risk and Achieve Safety Integrity
Authors: Hudson Abe
Published: April 2020

The objective of this paper is to highlight the Systems Engineering (SE) processes leveraged on a subsea BOP project. This paper focuses on aspects of Verification, Certification and Qualification and Safety. Key discussions include essential elements of SE and how they were leveraged and tailored to align with program constraints and success criteria to achieve successful deployment of the subsea BOP pilot system. With capital expenditures anticipated to fall more than 10% in 2020, employing SE methodologies is shown to reduce development costs while elevating product quality, reliability, and safety.
Could Barge LNG Replace FLNG?
Authors: Hernandez Edward Anthony , Highfield Timothy David , Forbes Thomas Gundersen , McLachlan Duncan James
Published: April 2020

Objectives / Scope

This paper will look at the technical, strategic and commercial benefits of Barge Liquefied Natural Gas (BLNG) technology in Deepwater and Onshore gas developments.

Methods, Procedures, Process

The majority of the FLNG vessels currently operating are ship-shaped and designed for offshore, over-field locations. However, this approach does not necessarily offer the optimised solution for gas monetisation. Equally where there is an abundant source of onshore gas, onshore liquefaction plants have generally been selected, e.g. US Gulf Coast, this may not be optimum.

An alternative solution in both these situations is BLNG, focused on nearshore positioning with liquefaction facilities mounted on a simple floating or grounded substructure with the balance of the systems (pre-processing, liquids handling, possibly storage etc.) decoupled from the liquefaction technology and in a separate location, such as a Central Processing FPSO in the deepwater or a gas processing facility near the development wells onshore.

Results, Observations & Conclusions

This paper addresses the following benefits of BLNG and why it's becoming an increasingly viable gas monetisation concept.

TechnicalSafety in both the operating and construction phases.This offers a "design one, build many" philosophy enabling a more efficient production line or "factory" approach to fabrication.A multiple module LNG train configuration enables liquefaction to closely and efficiently match gas production rates.Nearshore BLNG may be able to achieve a lower carbon footprint by utilising (a degree of) power from shore

CommercialWith multiple small LNG trains the reduction in export capacity during planned/unplanned shutdowns is limited to only the capacity of a single train.A facility's capacity can easily be increased by additional barges and contractible in late field life, as the field moves off plateau.

StrategicBLNG construction, fabrication and pre-commissioning can be performed in a dedicated yard rather than at a remote site. A controlled environment with an already skilled workforce in place.Potential for separate FLNG storage can be provided in a separate carrier moored alongside and not in the barge hull.BLNG is well suited to stranded gas as the barge is more mobile and amenable to relocating elsewhere for a new gas stream. Decommissioning is simplified, and environmental risks are reduced compared to in-situ decommissioning.

Finally, the paper will address a more certain approach to the selection of a BLNG solution where the optimum gas monetisation solution is identified in the concept phase front-end loading (FEL 1) of a project.

Novel / Additive Information

BLNG allows the disconnection of a deepwater or onshore development from the ‘conventional’ approaches to liquefaction; it offers an alternative to both deepwater FLNG and onshore liquefaction potentially allowing further optimisation in the construction, operations and overall economics of LNG developments.
Innovations in Installation and Pipeline Technology by the Johan Sverdrup Project
Authors: Nilsen-Nygaard Viktor , Hanssen Ståle , Groenewegen Matthijs , Vlaanderen Stef , Apeland Kjell Edvard , Berge Jan Olav , Instanes Frode , Armstrong Michael A. P.
Published: April 2020

In order to deliver on the ambitious schedule for the Johan Sverdrup development, the operator and the Johan Sverdrup-partners also needed to make some innovative bets on new technology. This paper explores two areas – innovations in installation and pipeline technology – that played a key role in the development of the mega-project.

In particular the decision to qualify and become the world`s first user of the single-lift installation technology developed for the vessel Pioneering Spirit ended up changing the very concept for construction, installation and completion of three of the four topsides that make up the Johan Sverdrup field center in the first phase of the development. The technology – developed by the installation contractor and qualified for first use worldwide by the operator – saved an estimated 2.5 million offshore manhours from the offshore completion phase, which significantly reduced safety risks and helped shave months off the development schedule. The first-ever use of the technology to install topsides took place in June 2018 with the single-lift installation of the drilling platform topsides on the Johan Sverdrup field. And in March 2019, the two remaining topsides weighing a total of 44,000 tonnes were lifted in place in the span of only 3 days, including the heaviest offshore lift ever executed with the installation of the 26,500 tonnes processing platform.

The paper also intends to explore how the same innovative mindset and focus also played a role in introducing new pipeline technology – in particular, the world`s first use of remote-controlled and diver-less hyperbaric welding of the ‘’36 oil export pipeline to the Johan Sverdrup riser platform. The paper also discusses how the project benefited from further industrialization of the hot-tapping technology used for the first time by the operator in 2012 on the Åsgard subsea project, when connecting the Johan Sverdrup gas export pipeline to the ‘live’ Statpipe gas pipeline.

Part 1 of this paper covers single lift installation of topsides, Part 2 covers diver less hyperbaric welding.
Applications of Wireline Formation Testing: A Technology Update
Authors: Partouche Ashers , Yang Bo , Tao Chen , Sawaf Tamim , Xu Lina , Nelson Keith , Chen Hua , Dindial Deo , Edmundson Simon , Pfeiffer Thomas
Published: April 2020

Wireline formation testing has evolved from discrete pressure measurements, introduced in the 1950s to measuring pressure gradients and fluid contacts since the 1970s. Technology introduced in the late 1980s and onwards added interval pressure transient testing, focused sampling, and downhole fluid analysis. Thirty years later, this paper shows data examples of a recently developed formation testing platform in a wide range of environments, and applications, that change how we plan, acquire, and use formation testing.

The dual-flow-line architecture of the formation testing platform is designed to systematically address shortcomings of legacy technology, enabling focused sampling in the tightest conventional formations, as well as transient testing in high mobility environments. Specialized pre-job planning software evaluates conveyance options to minimize friction and borehole contact, estimates the available flow rate, compares cleanup performance of the different inlets, and simulates transient testing responses. During the operation, the platform uses hardware embedded automation algorithms that execute routine tasks in a consistent and highly efficient manner, leaving more time for the user to focus on data quality and value of the measurements.

Case studies from Mexico, Norway, and the US demonstrate specific improvements in capability and performance. Field data from Mexico shows focused sampling of gas condensate from a heterogeneous submillidarcy carbonate formation in an HP/HT well drilled with oil-based mud. Controlled downhole decompression of crude oil in the flowline at a sampling station in Norway enabled real-time measurement of its bubblepoint pressure to within 6 psi of that measured in the laboratory. Another case study integrates accurate relative asphaltene gradients into an existing reservoir fluid study to prove reservoir connectivity across a large lateral distance in a producing field. Application of the dual packer subsystem demonstrates inflation within four minutes and pure oil samples within 90 minutes on station in a 1.5-md/cp fractured basement formation. The fine pump control at a low rate enabled sampling just below reservoir pressure in Alaska and a case from the Gulf of Mexico demonstrates the real-time impact of fluid properties on the understanding of reservoir architecture and completion design.

The presented examples highlight the impact of downhole automation, define the new operating envelope for formation testing in the most challenging environments, and highlight how the technology development leads to decision making on a broad reservoir scale by providing contextual answers rather than an accumulation of facts and figures.
ARIEL: An Autonomous Robotic System for Oil Spill Detection
Authors: Andreotti Marcelo , Peixoto Alessandro Jacoud , Monteiro João C , Halfeld Ricardo , Azambuja Ignácio , Vargas Lucas , Neves Alex F , Costa Ramon R , Ouvinã Ricardo , Valentim Samuel Simplício , Liporace Jéssica Paula , Norões Higuel Parga de Paiva , Coelho Rafael Botelho Duarte , Joyeux Sylvain , Vasconcelos Thiago Marinho , Vieira Gustavo Andreas , LeMerrer Anthony , Aguirre Rafael Pires
Published: April 2020

The development of oil spill detection technologies up until now have converged to the broad use of satellite-based SAR (Synthetic Aperture Radar). However, those systems present high amounts of false negatives results (oil spills that are not detected as such) and false positives (any other observation misinterpreted as an oil spill).

In order to address this issue, this research aims to produce an in-situ autonomous system which will perform oil spill monitoring more efficiently than the current methods applied by the Oil & Gas industry. Autonomy is key to reduce the unnecessary deployment of recovery crews at elevated financial cost and human safety risks on the case of false positives. Notably, the developed system is expected to drastically reduce the number of false negatives, enabling proper environmental safety within oil E&P infrastructure.

The proposed autonomous system (called ARIEL) is composed of an Unmanned Surface Vehicle (USV, or autonomous boat) and a Drone (specifically, a multirotor vertical take-off and landing drone). Those subsystems work together to perform a pre-programmed mission given by a human. Both are capable of navigating through a path made of waypoints, limiting a region of interest where oil spill is to be monitored.

The main benefits from the configuration of the system being developed is that it has much lower initial and maintenance costs when compared to current solution. Also, it can be easily deployed as a fleet, scaling its coverage and sweep rate.

Oil detection sensors are to be installed on both the autonomous vessel and drone, providing a double layer solution for eliminating errors. The first oil spill detection layer runs inside the drone, aiming at minimizing the probability of false negatives. This will be done via a visible and thermal camera package. The second layer runs in the USV via a fluorsensor. Firstly, it validates all possible incidents reported by the drone. Secondly, it double-checks all information gathered by the drone to check any oil spill incident that went unnoticed.

Furthermore, the USV is to be equipped with metocean sensors for adding the capability of tracking the oil slick movement and predicting its position in time. Measurements provided by wind and current sensors will be used to guide monitoring missions and can potentially be used to plan recovery operations.

Experimental analysis on both controlled environments (laboratorial and sheltered waters) and operational environment (open waters) are under execution. Not only results on sensory data processing but also the challenges overcome on the joint task of landing a drone on a moving vessel are presented is this work.
Relevance Of SCS&I For Green- And Brown Field Developments - Technology And Applicability
Authors: Thorkildsen Brede Andre , Rudh Mattias , Lopez Audrey , McKenzie Lachlan James , Pasquet Francois-Xavier
Published: April 2020

The development of Subsea Chemical Storage & Injection (SCS&I) technology is a continuation of the trend to move more of the hydrocarbon production system subsea. This is driven by a need to make exploitation of remote resources profitable; unlock single-line long tie-backs and subsea to shore architectures, and to enable tie-ins with otherwise constrained topside infrastructure. The SCS&I system is also a significant contributor to the development of "All-Electric" subsea architecture where the umbilical is reduced to a power and communication cable only.

TechnipFMC and Total are collaboratively working together to develop the SCS&I system and advance the technology.

The objectives of SCS&I can generally be divided into three categories: Reduced overall project cost by reducing umbilical cost and minimizing topside requirements (weight, space, modifications)De-bottlenecking of installed and/or damaged topside or subsea infrastructureEnabling injection of chemicals which cannot be transported to injection points via traditional means, for example high viscosity chemicals and/or chemicals with significant risk to personnel during topside handling

Within the wide variations of field architecture, step out distance, age of infrastructure and field depletion characteristics, the opportunities for successful application of SCS&I are huge. However, not every case is a good SCS&I case. End users and system integrators need to be able to identify where the SCS&I technology can make a difference in terms of reduced cost, increased production and/or improved flow assurance. The paper addresses this by illustrating break-even point in terms of step out distance for Green Fields and identifying typical cases where SCS&I can unlock value in Brown Fields.
Diseases and management of breeding stallions
Authors: Terblanche H. M.
Published: April 2020

No abstract available
The Veterinary Formulary Handbook of medicines used in veterinary practice
Authors: Debuf Yolande
Published: April 2020

No abstract available
The carbon dioxide laser scalpel
Authors: Durante E. J.
Published: April 2020

The CO₂-laser is currently used as a scalpel by a large number of medical surgeons, but in the field of veterinary surgery, relatively little has been published on the subject. A review of the origin of medical lasers, the basic physics of laser energy production and the characteristics of laser light was therefore considered necessary. This review includes a discussion on how the optical radiation generated by the different lasers is absorbed, the cutting power of the CO₂-laser, and the effect on healing, tensile strength and haemostasis when used in the skin, linea alba and gastrointestinal tract.
The ramifications of missionary proselytisation on Tiv culture: Lessons for contemporary critical biblical contextualisation
Authors: Tushima Cephas T.A.
Published: April 2020

Christianity, from its inception, has always demonstrated a conscious effort to communicate the gospel in ways that engender transformation. Yet the undying presence of African indigenous religious practices amongst evangelised African communities continues to be a worrisome enigma. The goal of this article is to examine the contextualisation practices, successes and failures of early western missionaries, using literary critical analysis of contemporary literature and cultural phenomenological analysis, and to propose approaches to a biblical inculturation of Christianity in contemporary indigenous societies. We focus on the over 100 years of Christianity in northern Nigeria, with particular emphasis on the Tiv of central Nigeria. The author’s research has shown that the relatively long presence of Christian mission work in Nigeria (especially amongst the Tiv) has not significantly altered the world view of the professed adherents of Christian faith, as it remains largely traditional rather than biblical. Consequently, we proposed the adoption of ethno-hermeneutic and community theologising to make for critical contextualisation of Christianity amongst indigenous people. The proposed critical contextualisation, is essential for rooting Christianity in native populations without uprooting them from their cultures, and for ensuring neither the gospel truth claims nor the Christian world view is surrendered to native cultures in the process of indigenising the gospel.Intradisciplinary and/or interdisciplinary implications: This article highlights the importance of a holistic interdisciplinary approach to evangelisation, requiring the interplay of anthropology, missiology, hermeneutics, and dogmatic and exegetical theology.
Measurement of thoracic and lumbar pedicle dimensions in Nigerians using computed tomography
Authors: Badmus Olakunle , Ogbe Patricia , Olowoyeye Omodele A. , Akinsulire Adewole , Omidiji Olubukola
Published: April 2020

Background:

Pedicle screws are often used to stabilise the spine. They afford the benefit of a three-column control of the spine. The technique of pedicle screw insertion is familiar and has a well-documented safety profile during lumbar and thoracic spinal surgery. However, complications such as cerebrospinal fluid leakage due to pedicle screw misplacement, neurological irritation and pedicle penetration may occur. Therefore, knowledge of the dimensions of spinal pedicles is necessary for the fixation of pedicular screws to avoid possible complications.

Aims:

The aim of this study was to determine the maximal diameter and axial length of thoracic and lumbar pedicles in a homogenous African population using computed tomography (CT). This would establish normative data on the average size of pedicle screws that would be required during the surgery, hence maximising pull-out strength while reducing the possibility of revision of the pedicle screw placement.

Methods:

It is a retrospective study where the transverse pedicle width, axial pedicle length and sagittal pedicle width of T1–L5 were measured on 100 patients; 50 males, 50 females with normal spinal architecture using a 128-slice Toshiba CT scanner.

Results:

The mean axial length in the thoracic and lumbar vertebrae ranged from 31.76 ± 2.92 mm (T1) to 43.02 ± 3.32 mm (T12) and from 45.07 ± 2.40 mm (L5) to 46.32 ± 2.28 mm (L3), respectively. The mean TPW at the thoracic and lumbar vertebrae ranged from 4.53 ± 0.69 (T4) to 7.78 ± 1.31 mm (T12) and from 6.81 ± 1.25 mm (L1) to 12.95 ± 1.49 mm (L5), respectively. The mean sagittal diameter of thoracic and lumbar vertebrae ranged from 5.78 ± 1.07 mm (T1) to 10.98 ± 1.37 (T12) and from 9.51 ± 1.31 mm (L2) to 9.78 ± 1.61 (L4), respectively.

Conclusion:

The dimensions of thoracic and lumbar pedicles measured in this study vary with those obtained from other populations. This strengthens the case for customising the existing range of spinal pedicle screws according to local population characteristics.
Смешанные задачи для сильно эллиптических
дифференциально-разностных уравнений в цилиндре
Authors: Liiko Viktoriia Vladimirovna , Skubachevskii Alexander Leonidovich
Published: April 2020

Рассматриваются смешанные краевые задачи для сильно
эллиптических дифференциально-разностных уравнений
и нелокальные смешанные задачи для эллиптических
дифференциальных уравнений в цилиндре. Установлена
взаимосвязь указанных задач, а также их однозначная
разрешимость.
Библиография: 21 название.
О многомерной проблеме Терри для кубческого многочлена
Authors: Jabbarov (Dzhabbarov) Ilgar Shikar oglu
Published: April 2020

В статье получена новая верхняя оценка показателя сходимости
особого интеграла проблемы Терри. Результат основан
на представлении особого интеграла в виде поверхностного интеграла,
распространенного на многообразие решений системы уравнений
проблемы Терри. Получены новые оценки
возникающих поверхностных интегралов, сводящие вопрос об оценке
к исследованию некоторых операторов с дискретным спектром,
с использованием максимальных миноров.
Библиография: 21 название.
SAE J1939 Functional Safety Communications Protocol
Authors:   Truck Bus Control and Communications Network Committee
Published: April 2020

This document provides the technical requirements for implementing the SAE J1939 Functional Safety Communication Protocol in a manner determined suitable for meeting industry applicable functional safety standards.