bluuebunny/crossref_metadata_2025_split huggingface dataset:
Next-Generation Hybrid Drill Bit Produces Exceptional Drilling Dynamics and Time-Saving Improvements
Authors: Bone Kim , Bradley Ben , Kale Ibrahim 
Published: April 2019

Abstract
An offshore field has presented a challenging intermediate drilling application. The 2200-m section was drilled in a 17.5-in. hole to 3700-m true vertical depth. The lithogy of the section is variable, beginning with a soft claystone, followed by several sandstone formations, an 1100-m interbedded sandstone and claystone interval, a 125-m hard carbonate, and 50m of softer claystone before the casing point. The challenges presented in recent offset wells included high stick/slip, high levels of drill bit cutting structure wear and drill bit body erosion. Polycrystalline diamond compact (PDC) bit designs utilized in recent offsets varied from six to nine blades, with the interval requiring two or three bits to complete the interval.
Based on results from other challenging offshore applications, including improved durability and drilling dynamics, the next-generation PDC and roller-cone hybrid drill bit (hybrid) with improved design features was selected for the application. Improved design features included a new increased blade count concept, combined with a sharp and dense roller-cone cutting structure.
The application of the next-generation hybrid drill bit design delivered a reduction in drilling time and an improvement to drilling dynamics compared to offset wells drilled with conventional technology. Compared to the best offset well drilled in 17.5-in. hole a reduction in total drilling time of 59.4hrs (31%) was achieved. The reduction in drilling time resulted from both an increase in on bottom ROP of 32% and the removal a bit trip (19 hours) due to the interval being drilled in one run for the first time. Associated with the reduced drilling time, improvements in drilling dynamics were observed with stick/slip reduced by 73%.
This paper illustrates the study of the application, applied learnings from new technology developments in hybrid technology evolution, and the subsequent improvements in drilling dynamics that resulted in improved penetration rates and cost savings in this challenging application.
Creative Solution to Re-Establish Control of a Subsea Field with Failed Umbilical
Authors: Mao Jiayou 
Published: April 2019

Abstract
LH4-1 oil field is a subsea tie-back which was developed by CNOOC in 2012. After a short period of production, the subsea control umbilical started with low Insulation Resistance (IR) of its electric control quads. Extensive trouble shooting work immediately started. The trouble was identified to be on the main umbilical. The subsea electric control was swapped to the spare quad. After about a year, the spare quad also had zero IR. In order to resume the subsea control, feasibility of using the spare Medium Voltage (MV) power cable triads as control channel was studied immediately. The idea of using three core triad to establish dual communication channels with two frequency bands was thoroughly studied and it was found theoretically feasible. Originally the communication was one loop controls 4 wells, now with the new arrangement one loop controls 8 wells, 3-core with one as common return makes two loops. So the new MV cable communication configuration can still achieve subsea control with 100% redundancy. Subsea special bridge flyleads were designed and manufactured to convert the 70mm2 3-core MV flylead to 10mm2 4-core communication flylead. Offshore intervention work was done in 2014. After installation, subsea communication to all 8 wells was re-established as expected. The signal qualitywas much better that the original umbilical possibility due to the large MV copper cores.
AI-Driven Well Timelines for Well Optimization
Authors: Dalgliesh Jeff , Jones Allen , Palanisamy Arulmozhi , Schmauser Justin 
Published: April 2019

Artificial intelligence and machine learning algorithms provide energy companies with the possibility to digitally re-construct well histories, using both public and company specific historical well data.
In this paper we discuss how oil and gas companies are creating a digital knowledge layer for oil and gas wells that provide a timeline of significant well events. Examples of key timeline events include, when drilling problems such as kicks happened, when blowout preventers were tested, when bottom hole pressures were taken, and when well interventions were done.
This new generation of AI-driven applications are powered by a combination of a computational knowledge graphs and AI algorithms. These AI algorithms encode the expertise of subject-matter experts such as Petro-technical engineers and combine their experience with decades of historical well-events data extracted from databases, documents, and sensors to automatically create well event timelines. This technology enriches and combines companies’ internal siloed well data with public well data to create an integrated digital knowledge layer for wells. Engineers can optimize the life cycle of the wells by visually exploring this interactive timeline to understand and make decisions about the well.
Petro-technical engineers have easy access to knowledge related to people, equipment, vendors, wells and more, so they can make better, more informed decisions faster. We show how we train the application's machine learning algorithms to read hundreds of thousands of historical reports to harvest knowledge about the well and store the extracted knowledge in an enterprise digital knowledge layer. By using the knowledge harvested and captured by this AI-driven application, experienced engineers can make better decisions that optimize the operations of their upstream assets.
From Prospect to Life of Field Service – The Role and Impact of Well Installation/ Intervention from a Subsea EPC Contractor's Point of View
Authors: Bay Lars Skoe 
Published: April 2019

Abstract
Being a global Subsea and Topside EPC contractor is often synonym with having an extensive portfolio of subsea production system solutions, sometimes including installation and well intervention systems such as landing string systems, riser based intervention systems and riser less intervention systems. However, unlike companies who focus specifically on subsea well intervention, and typically targets life of field opportunities, these EPC contractors might have this technology is in-house which enables cross discipline discussions already during concept studies and Front End Engineering Design studies (FEEDs). This enables contractor and client to select suitable technology not only based on equipment functionality and hardware cost, but highlights the operational impact such selections have both regarding installation of the equipment, and well intervention service throughout the lifetime of the field.
In a reference project a global EPC company is the main contractor for the engineering, procurement, construction and installation of the Subsea Production System (SPS) equipment in projects related to two large field developments West of Africa for a major operator. A total of 92 vertical subsea x-mas trees (VXTs) was awarded between 2013-2014 designed to be installed in depths down to approximately 2000m. In this case it was decided to install the tubing hangers using simplified landing string technology, while a riser based light intervention system was selected to provide flexible options for VXT installation, well clean-up/ flow back and life of field well intervention. A cross-vendor workover control system was selected to be used in both installation and intervention modes, allowing the operator to perform well interventions on existing subsea infrastructure in the region with 3rd party XT vendors, in addition to the planned field developments.
This paper will discuss how an EPC contractor can exploit the benefits of being both a subsea EPC contractor and an installation and well intervention service provider. The referenced project will be used as a case study, starting with the early phase studies, to show how decisions related to installation and intervention systems can greatly impact the XT selection and life of field strategy, and hence the configuration of the overall SPS and corresponding tooling. The philosophies around rig related services such as this connects the operator spend on SPS, SURF and drilling scope, and can greatly impact the overall project economics due to synergies across the distinct areas of investment. Furthermore, the paper discusses the importance of having a holistic approach when considering an intervention system for late life management, why it is beneficial to discuss such strategies at an early stage, and the benefits this brings to the end client over time.
Mooring Line Failure Detection Using Machine Learning
Authors: Jaiswal Vivek , Ruskin Alex 
Published: April 2019

Offshore floating vessel mooring failure and subsequent loss of station can have catastrophic consequences for the vessel and the associated subsea infrastructure. Therefore, integrity management and timely detection of mooring failure is critical. Traditional methods of failure detection rely on line tension measurements and watch circle approaches. Both these approaches have limitations and are not reliable. Alternate methods of detecting line failure are therefore required.
This paper discusses a novel approach of using measured vessel positions and 6-degrees-of-freedom accelerations along with a deep machine learning algorithm to detect mooring line failure in near real time. Results from a numerical case study for a turret moored FPSO with over 4000 test cases demonstrate that this approach can accurately identify failed mooring line cases over 99% of the time.
Correlation of Finite Element Analysis FEA Predicted Residual Strength of Degraded Offshore Mooring Chains with Test Data
Authors: Farrow Gary H. , Potts Andrew E. , Dimopoulos Simon , Kilner Andrew A. 
Published: April 2019

Abstract
The first phase of the Chain FEARS (Finite Element Analysis of Residual Strength) Joint Industry Project (JIP) aimed to develop guidance for the determination of a rational discard criteria for mooring chains subject to severe pitting corrosion which, based on current code requirements, would otherwise require immediate removal and replacement.
Critical to the ability to establish rational discard criteria, is the ability to accurately predict the residual strength of degraded chain, and to have as a benchmark for loss in strength, an accurate estimate of the chain in its as-new condition. With a correlated FEA method for residual strength prediction and a benchmark for as-new condition capacity, it would then be possible to establish a theoretical relationship between different types of degradation and mooring chain capacity loss, from which rational discard criteria would be derived.
To this end the Chain FEARS JIP first developed a Finite Element Analyses (FEA) residual capacity assessment method to accurately predict the residual strength of degraded chains. A number of assessments were carried out to establish the sensitivity of the Predicted Break Load (PBL) to both engineering parameters such as friction coefficient, and numerical modelling techniques. The developed method was validated by the correlation of the PBL against a number of physical break tests.
This paper presents a review of the break strength test data of pitting corrosion degraded chain links. The FEA modelling methodology based Predicted Break Load (PBL) are compared with the test data Actual Break Load (ABL) along with the sensitivity of engineering parameters and numerical model modelling techniques on predictions. The developed FEA method accurately predicts the location of the ‘failure’ within the chain string and the ductile necking failure mode, determined to be the prevalent mode of failure for the chain links samples considered in this study. The degree of correlation between PBL and ABL confirms that accurate prediction of the effects of corrosion degradation consequent on uniform and large pitting corrosion can be accurately predicted by use of the Finite Element Method.
The developed FEA method was also employed to establish a benchmark for the strength capacity of as-new condition links as presented in [1], the basis for assessing the relationship between corrosion degradation and residual chain link capacity [2] and a basis for a multi-axial fatigue assessment method to establish the fatigue capacity of as-new and degraded chain links [3,4,5].
Developing Probabilistic Risk Assessment, PRA, for a BOP System Reliability
Authors: Holmes John Steven , Shah Viral 
Published: April 2019

Abstract
Recent regulatory changes have moved in the direction of more oversight and more prescriptive solutions. One of the areas that can help operators and drillers alike deal with the new regulations is improved risk analysis. This paper addresses a methodology for Probabilistic Risk Analysis (PRA) modeling of blowout preventer (BOP) systems. The PRA utilizes a combination of event trees and fault trees to determine the probability of a hazard under a given set of conditions. The fault trees are populated with reliability data from the best available sources.
Traditional BOP risk analysis was done on a deterministic approach. The probabilistic approach will allow a logical method to assess top level hazards resulting from specific component failures. This approach has been used in other industries such as nuclear power and space exploration. A method of combining testing intervals with PRA results to determine the probability of failure on demand is also included.
ABB Subsea Power JIP – Going the Distance
Authors: Ingebrigtsen Stian , Vatland Svein , Pretlove John , Nesheim Henning 
Published: April 2019

ABB is running a joint project with Equinor, Total and Chevron to develop technologies for subsea power transmission, distribution and conversion. The output will form a critical part of future advanced subsea field developments. Started in 2013, the project reached a major milestone in late 2017 when the first full-scale prototype of the variable speed drive (VSD) passed a shallow water test. Final preparations are now underway for a 3000-hour test of the complete subsea power system with two VSDs in a parallel configuration combined with subsea switchgear and controls.
The new solution will ultimately mean operators can free up topside space, or use no topside installation whatsoever, yielding significant cost and safety benefits. It is an extremely challenging endeavour, not only due to the harsh conditions to which the equipment will be subjected, but also because of the considerable reliability required. The equipment, the medium voltage (MV) switchgear, control and low voltage (LV) distribution equipment and the VSDs, must be able to run without intervention for many years.
The VSD's successful shallow-water test is the subject of a separate OTC paper; here, we present the highlights in the context of the wider project and particularly the steps taken to build confidence along the way that the proposed solution will be fit for purpose when fully launched. Readers will gain insights into the key steps of this cutting-edge project. These include modifying prototypes of the equipment based on rounds of simulations, laboratory assessments (eg accelerated aging, vibration and shock testing) and water testing.
As such an undertaking has never been achieved before, it is a journey with considerable learnings to be shared not only upon completion but also en-route. As we approach the goal which is anticipated by the end of 2019, it is appropriate to begin to share what we have learnt as we have been going the distance.
uROV – The Next Generation IMR Platform Utilizing Supervised Autonomy
Authors: Vincent Jack Heath , Sevinc Nazli Deniz , Herbst Neil Andrew 
Published: April 2019

Abstract
Autonomous Underwater Vehicles (AUVs) have shown promise to disrupt Inspection, Maintenance, and Repair (IMR) activities typically performed by Remotely Operated Vehicles (ROVs) tethered to large, expensive vessels on the surface. There are many concepts and projects within oil and gas that are focused in utilizing the efficiencies of these AUVs in novel deployment framework.
A novel autonomous vehicle platform in this domain is being developed called uROV (untethered ROV). The uROV vision has three main elements to bring to the IMR market. The first is to develop efficient deployment solutions such that IMR vessel expenditure is reduced or removed. The second is to bring next generation sensing technology to the market and integrate into the uROV platform. This is aimed at collecting better and more insightful data to use for integrity evaluation. The third main element is to bring digital enablement to the market through connectivity, data process automation, and visualization.
Application of Coupled Simulation Optimization Methodology to Study Dual Nitrogen Expander Liquefaction Response to Feed Gas Variations from an Optimized Design
Authors: Tierling Shane , Attaway Doug 
Published: April 2019

Abstract
Interest in dual nitrogen expander liquefaction technology for floating liquefied natural gas (FLNG) applications is driven by the following factors: inflammable refrigerantsimplicitylow weightno refrigerant sloshing or maldistribution due to motionquick start-upeasy adjustment for changing feed conditions
The downside is that dual nitrogen expander technology offers significantly lower liquefaction efficiency than competing FLNG technologies. The proper selection and sizing of the upstream gas treating and liquefaction system is critical during Front End Engineering Design (FEED) to ensure that the system footprint, weight and center-of-gravity is appropriately estimated as this effects the sizing, design and performance of the floating hull.
This paper will demonstrate how the process design can be optimized over a range of feed compositions or conditions if some flexibility is built into the liquefaction heat exchange during design. This preserves flexibility as a key advantage of the technology. The intent is to reduce process inefficiencies and promote competitiveness with other technologies. Note that there are many different nitrogen expander technology configurations available in the market. The configuration used here is generic and used to demonstrate the optimization concept.
With 10 independent variables and coupling between the variables, this optimization is difficult to perform using simple manual methods. Therefore we will employ a coupled simulation-optimization method.
This paper also provides insight to the application of coupled simulation-optimization to problems, as illustrated by the specific application to a dual titrogen expander technology. Although this method is applicable to the initial design of liquefaction processes, the focus here is on off-design optimization of the facility later in the design cycle and in operation.
This optimization methodology is shown to provide benefits beyond the initial process design, extending into the operation of the facility. The methodology does not rely upon a specific tool set and there are non-academic tools that support this approach.
The Fusion Bonded Joint: A New Way of Joining HDPE Lined Pipes for Reeling and Fatigue Sensitive Applications
Authors: Lirola François 
Published: April 2019

Abstract
Corrosion protection is a key aspect of all subsea developments. Indeed the complexity of subsea pipe maintenance and repair makes it necessary to provide solutions suitable for the full life time of the field. Though sensitive applications such as production lines transporting corrosive compounds, CO2 and H2S for instance, immediately comes to mind when mentioning corrosion, other applications, though seemingly less demanding, also require to be properly addressed from a corrosion perspective. One of these applications is water injection lines.
Corrosion in these lines is usually tackled with using a wide range of approaches depending on operation philosophy: topside treatment, corrosion allowance, cladding or plastic liners. A balance usually has to be found between how extensively the injected water is processed topsides and what other corrosion mitigations methods are deployed. This assessment should be carefully conducted the selected approach will impact procurement and installation costs. For instance, increasing the pipe wall thickness to cope with corrosion would results in higher lay vessel installation capabilities as well as longer welding time while relying on clad pipes would negatively impact procurement costs and require more complex NDT methods to be implemented.
Plastic liners offer a relevant alternative though their implementation has to be carefully assessed so as to ensure it remains cost competitive. To that extent, the Fusion Bonded Joint has been developed and qualified. This system ensures the continuity of the plastic layer at carbon steel weld locations while limiting the offshore cycle time thus preserving lay rates of the installation vessel.
This paper includes an overview the technology itself as well as a summary of the extensive qualification campaign that has been carried out. A global overview of the testing campaign will be provided from the early stages of the development to the full scale testing of the technology in an environment representative of its actual operating conditions. Topics discussed will include: prototyping of the system and associated tools, qualification of the electro-fusion welding process as well as its control and qualification of the carbon steel welding process. The main challenges and outcomes of tests performed will be presented and discussed. A focus on the specificities of the fatigue testing campaign will be presented including fatigue string design as well as fatigue performance of plastic electro-fusion weld. Eventually, the applicability of the FBJ to reeling will be discussed.
Drilling Permit Application Hurdles for Gulf of Mexico Oil and Gas Exploration
Authors: Crouch Don , Hoefler John 
Published: April 2019

Abstract
The objective of this paper is to provide insight into a few of the dominant hurdles applicants experience when preparing information for review by the US Bureau of Safety and Environmental Enforcement (BSEE) when applying for a permit to drill. Numerous requirements for the Application for Permit to Drill (APD) exist that can present a complex task of aligning documentation and information across multiple process participants that are not always apparent at the outset. The included information will follow the general path that exists in BSEE APD development, including 30 CFR §250.410, which defines some of those numerous requirements.
The paper will include BSEE requirements in 30 CFR §250.410-16, -18 "How do I obtain approval to drill a well?" the BSEE APD Development Phase Flow-chart, 30 CFR §250.731 "BOP Systems and … Components", §250.713 "if I plan to use a MODU", and additional required compliance statements, and explain how the sources of information can differ from project to project and within groupings of defined requirement sets (BSEE 2016).
The paper will also include a brief review of requirements set out by other parts of 30 CFR §250, not specifically delineated as part of the APD, but specifically required for execution.